10-Q

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 June 30, 2021

Or

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

Commission file number 1-15759

CLECO CORPORATE HOLDINGS LLC

(Exact name of registrant as specified in its charter)

Louisiana	72-1445282
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

2030 Donahue Ferry Road, Pineville, Louisiana    71360-5226

     (Address of principal executive offices)                         (Zip Code)

Registrant’s telephone number, including area code: (318) 484-7400

Commission file number 1-05663

CLECO POWER LLC

(Exact name of registrant as specified in its charter)

Louisiana	72-0244480
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

2030 Donahue Ferry Road, Pineville, Louisiana    71360-5226

     (Address of principal executive offices)                         (Zip Code)

Registrant’s telephone number, including area code: (318) 484-7400

Securities registered pursuant to Section 12(b) of the Act:
Cleco Corporate Holdings LLC: None	Cleco Power LLC: None

Indicate by check mark whether the Registrants: (1) have 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 Registrants were required to file such reports) and (2) have been subject to such filing requirements for the past 90 days. Yes ☐ No ☒

Indicate by check mark whether the Registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the Registrants were required to submit such files). Yes ☒ No ☐

Indicate by check mark whether Cleco Corporate Holdings LLC is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See 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 accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether Cleco Power LLC is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See 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 accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the Registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act)  Yes ☐ No ☒

Cleco Corporate Holdings LLC has no common stock outstanding. All of the outstanding equity of Cleco Corporate Holdings LLC is held by Cleco Group LLC, a wholly owned subsidiary of Cleco Partners L.P.

Cleco Power LLC, a wholly owned subsidiary of Cleco Corporate Holdings LLC, meets the conditions set forth in General Instructions H(1)(a) and (b) of Form 10-Q and is therefore filing this Form 10-Q with the reduced disclosure format.

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

This Combined Quarterly Report on Form 10-Q (this “Quarterly Report on Form 10-Q”) is separately filed by Cleco Corporate Holdings LLC and Cleco Power LLC. Information in this filing relating to Cleco Power LLC is filed by Cleco Corporate Holdings LLC and separately by Cleco Power LLC on its own behalf. Cleco Power LLC makes no representation as to information relating to Cleco Corporate Holdings LLC (except as it may relate to Cleco Power LLC) or any other affiliate or subsidiary of Cleco Corporate Holdings LLC.

This Quarterly Report on Form 10-Q should be read in its entirety as it pertains to each respective Registrant. The Notes to the Unaudited Condensed Consolidated Financial Statements for the Registrants and certain other sections of this Quarterly Report on Form 10-Q are combined.

TABLE OF CONTENTS
		PAGE
GLOSSARY OF TERMS		3
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS		5
PART I	Financial Information
ITEM 1.	Cleco — Condensed Consolidated Financial Statements (Unaudited)	7
	Cleco Power — Condensed Consolidated Financial Statements (Unaudited)	16
	Notes to the Unaudited Condensed Consolidated Financial Statements	25
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	49
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	65
ITEM 4.	Controls and Procedures	67
PART II	Other Information
ITEM 1.	Legal Proceedings	68
ITEM 1A.	Risk Factors	68
ITEM 6.	Exhibits	68
	Signatures	69

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

GLOSSARY OF TERMS

Abbreviations or acronyms used in this filing, including all items in Parts I and II, are defined below.

ABBREVIATION OR ACRONYM	DEFINITION
2016 Merger	Merger of Merger Sub with and into Cleco Corporation pursuant to the terms of the Merger Agreement which was completed on April 13, 2016
2016 Merger Commitments	Cleco Partners’, Cleco Group’s, Cleco Holdings’, and Cleco Power’s 77 commitments to the LPSC as defined in Docket No. U-33434
401(k) Plan	Cleco Power 401(k) Savings and Investment Plan
ABR	Alternate Base Rate which is the greater of the prime rate, the federal funds effective rate plus 0.50%, or LIBOR plus 1.0%
Acadia	Acadia Power Partners, LLC, previously a wholly owned subsidiary of Midstream. Acadia Power Partners, LLC was dissolved effective August 29, 2014.
Acadia Unit 1	Cleco Power’s 580-MW, combined cycle power plant located at the Acadia Power Station in Eunice, Louisiana
Acadia Unit 2	Entergy Louisiana’s 580-MW, combined cycle power plant located at the Acadia Power Station in Eunice, Louisiana, which is operated by Cleco Power
ACE	Affordable Clean Energy
ADIT	Accumulated Deferred Income Tax
AFUDC	Allowance for Funds Used During Construction
Amended Lignite Mining Agreement	Amended and restated lignite mining agreement effective December 29, 2009
AMI	Advanced Metering Infrastructure
AOCI	Accumulated Other Comprehensive Income (Loss)
ARO	Asset Retirement Obligation
Big Cajun II, Unit 3	A 588-MW coal-fired generating unit at Cleco Cajun’s plant site in New Roads, Louisiana. Cleco Cajun has a 58% ownership interest in the capacity of Big Cajun II, Unit 3.
CARES Act	Coronavirus Aid, Relief, and Economic Security Act of March 2020
CDC	Centers for Disease Control and Prevention
CECL	Current Expected Credit Losses
CEO	Chief Executive Officer
CFO	Chief Financial Officer
CIP	Critical Infrastructure Protection
Cleco	Cleco Holdings and its subsidiaries
Cleco Cajun	Cleco Cajun LLC (formerly Cleco Energy LLC, a wholly owned subsidiary of Cleco Holdings) and its subsidiaries
Cleco Cajun Transaction	The transaction between Cleco Cajun and NRG Energy in which Cleco Cajun acquired all the membership interest in South Central Generating, which closed on February 4, 2019, pursuant to the Purchase and Sale Agreement, which includes the Cottonwood Sale Leaseback
Cleco Corporation	Pre-2016 Merger entity that was converted to a limited liability company and changed its name to Cleco Corporate Holdings LLC on April 13, 2016
Cleco Group	Cleco Group LLC, a wholly owned subsidiary of Cleco Partners
Cleco Holdings	Cleco Corporate Holdings LLC, a wholly owned subsidiary of Cleco Group
Cleco Katrina/Rita	Cleco Katrina/Rita Hurricane Recovery Funding LLC, a wholly owned subsidiary of Cleco Power
Cleco Partners	Cleco Partners L.P., a Delaware limited partnership that is owned by a consortium of investors, including funds or investment vehicles managed by Macquarie Infrastructure and Real Assets Inc., British Columbia Investment Management Corporation, John Hancock Financial, and other infrastructure investors
Cleco Power	Cleco Power LLC and its subsidiaries, a wholly owned subsidiary of Cleco Holdings
Como 1	Como 1, L.P., currently known as Cleco Partners
Cottonwood Energy	Cottonwood Energy Company LP, a wholly owned subsidiary of Cleco Cajun. Prior to the closing of the Cleco Cajun Transaction on February 4, 2019, Cottonwood Energy was an indirect subsidiary of South Central Generating.
Cottonwood Plant	Cleco Cajun’s 1,263-MW, natural-gas-fired generating station located in Deweyville, Texas
Cottonwood Sale Leaseback	A lease agreement executed and delivered between Cottonwood Energy and a special-purpose entity that is a subsidiary of NRG Energy pursuant to which NRG Energy will lease back the Cottonwood Plant and will operate it until no later than May 2025.
Coughlin	Cleco Power’s 775-MW, combined-cycle power plant located in St. Landry, Louisiana
COVID-19	Coronavirus disease 2019 and the related global outbreak that was subsequently declared a pandemic by WHO in March 2020
CPP	Clean Power Plan
CSAPR	Cross-State Air Pollution Rule
DHLC	Dolet Hills Lignite Company, LLC, a wholly owned subsidiary of SWEPCO
Diversified Lands	Diversified Lands LLC, a wholly owned subsidiary of Cleco Holdings
Dolet Hills	A facility consisting of Dolet Hills Power Station, the Dolet Hills mine, and the Oxbow mine
Dolet Hills Power Station	A 650-MW generating unit at Cleco Power’s plant site in Mansfield, Louisiana. Cleco Power has a 50% ownership interest in the capacity of the Dolet Hills Power Station.
EAC	Environmental Adjustment Clause

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

ABBREVIATION OR ACRONYM	DEFINITION
EBITDA	Earnings before interest, income taxes, depreciation, and amortization
Entergy Gulf States	Entergy Gulf States Louisiana, LLC
Entergy Louisiana	Entergy Louisiana, LLC
EPA	U.S. Environmental Protection Agency
ERO	Electric Reliability Organization
Evangeline	Cleco Evangeline LLC, a wholly owned subsidiary of Midstream
FAC	Fuel Adjustment Clause
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
Fitch	Fitch Ratings, a credit rating agency
FTR	Financial Transmission Right
FRP	Formula Rate Plan
GAAP	Generally Accepted Accounting Principles in the U.S.
IRS	Internal Revenue Service
kWh	Kilowatt-hour(s)
LIBOR	London Interbank Offered Rate
LMP	Locational Marginal Price
Louisiana Generating	Louisiana Generating, LLC, a wholly owned subsidiary of South Central Generating
LPSC	Louisiana Public Service Commission
LTSA	Long-Term Parts and Service Agreement between Cottonwood Energy and a third party, dated January 19, 2001, that Cleco Cajun assumed as a result of the Cleco Cajun Transaction to provide maintenance services related to the Cottonwood Plant
Madison Unit 3	A 641-MW generating unit at Cleco Power’s plant site in Boyce, Louisiana
Merger Agreement	Agreement and Plan of Merger, dated as of October 17, 2014, by and among Cleco Partners, Merger Sub, and Cleco Corporation relating to the 2016 Merger
Merger Sub	Cleco MergerSub Inc., previously an indirect wholly owned subsidiary of Cleco Partners that was merged with and into Cleco Corporation, with Cleco Corporation surviving the 2016 Merger, and Cleco Corporation converting to a limited liability company and changing its name to Cleco Holdings
Midstream	Cleco Midstream Resources LLC, a wholly owned subsidiary of Cleco Holdings
MISO	Midcontinent Independent System Operator, Inc.
MMBtu	One million British thermal units
Moody’s	Moody’s Investors Service, a credit rating agency
MW	Megawatt(s)
MWh	Megawatt-hour(s)
NERC	North American Electric Reliability Corporation
Not Meaningful	A percentage comparison of these items is not statistically meaningful because the percentage difference is greater than 1,000%
NRG Energy	NRG Energy, Inc.
Other Benefits	Includes medical, dental, vision, and life insurance for Cleco’s retirees
Oxbow	Oxbow Lignite Company, LLC, 50% owned by Cleco Power and 50% owned by SWEPCO
Perryville	Perryville Energy Partners, L.L.C., a wholly owned subsidiary of Cleco Holdings
Purchase and Sale Agreement	Purchase and Sale Agreement, dated as of February 6, 2018, by and among NRG Energy, South Central Generating, and Cleco Cajun
Registrant(s)	Cleco Holdings and/or Cleco Power
Rodemacher Unit 2	A 523-MW generating unit at Cleco Power’s plant site in Boyce, Louisiana. Cleco Power has a 30% ownership interest in the capacity of Rodemacher Unit 2.
ROE	Return on Equity
RTO	Regional Transmission Organization
S&P	S&P Global Ratings, a division of S&P Global Inc, a credit rating agency
SEC	U.S. Securities and Exchange Commission
SERP	Supplemental Executive Retirement Plan
South Central Generating	South Central Generating LLC, formerly NRG South Central Generating LLC
SSR	System Support Resource
Support Group	Cleco Support Group LLC, a wholly owned subsidiary of Cleco Holdings
SWEPCO	Southwestern Electric Power Company, an electric utility subsidiary of American Electric Power Company, Inc.
TCJA	Federal tax legislation commonly referred to as the Tax Cuts and Jobs Act of 2017
Teche Unit 3	A 359-MW generating unit at Cleco Power’s plant site in Baldwin, Louisiana
WHO	World Health Organization

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q includes forward-looking statements. All statements other than statements of historical fact included in this Quarterly Report on Form 10-Q are forward-looking statements, including, without limitation, future capital expenditures; business strategies; goals, beliefs, plans, and objectives; competitive strengths; market developments; development and operation of facilities; growth in sales volume; meeting capacity requirements; expansion of service to existing customers and service to new customers; future environmental regulations and remediation liabilities; electric customer credits; and the anticipated outcome of various regulatory and legal proceedings. Although the Registrants believe that the expectations reflected in such forward-looking statements are reasonable, such forward-looking statements are based on numerous assumptions (some of which may prove to be incorrect) and are subject to risks and uncertainties that could cause the actual results to differ materially from the Registrants’ expectations. In addition to any assumptions and other factors referred to specifically in connection with these forward-looking statements in this Quarterly Report on Form 10-Q, the following list identifies some of the factors that could cause the Registrants’ actual results to differ materially from those contemplated in any of the Registrants’ forward-looking statements:

•changes in environmental laws, regulations, decisions and policies, including present and potential environmental remediation costs, restrictions on greenhouse gas emissions to mitigate concerns over global climate changes, possible effects on Cleco’s generation resources, or prohibitions or restriction on new or existing services, and Cleco’s compliance with these matters,

•state and federal regulatory decisions or related judicial decisions disallowing or delaying recovery of capital investments, operating costs, commodity costs, the ordering of refunds to customers and discretion over allowed return on investment,

•the loss of regulatory accounting treatment, which could result in the write-off of regulatory assets and the loss of regulatory deferral and recovery mechanisms,

•economic, regulatory, or workforce impacts related to pandemics, including the COVID-19 pandemic,

•the possibility of stranded costs with respect to assets that may be retired as a result of new climate legislation, technological advances, a shift in demand, or legal action,

•changes in climate and weather conditions, including natural disasters such as wind and ice storms, hurricanes, floods, and droughts, and Cleco Power’s ability to recover restoration costs associated with these events,

•the ability of Cleco’s customers to continue paying their utility bills due to rising costs related to hurricanes, ice storms, or other weather events,

•economic conditions in Cleco’s service areas, including the economy’s effects on customer demand for utility services,

•Cleco’s ability to recontract existing power purchase agreements or secure future power purchase agreements with wholesale customers,

•mechanical breakdowns or other incidents that could impair assets and disrupt operations of any of Cleco’s generation facilities, transmission and distribution systems, or other operations and may require Cleco to purchase replacement power or incur costs to repair the facilities,

•growth or decline of Cleco’s customer base, or decline in existing services, including the effects of the trend toward distributed generation at customer sites, the loss of key suppliers for fuel, materials, or services, or other disruptions to the supply chain,

•wholesale and retail competition, including alternative energy sources, growth in customer-owned power resource technologies that displace utility-supplied energy or that may be sold back to the utility, and alternative energy suppliers and delivery arrangements,

•blackouts or disruptions of interconnected transmission systems (the regional power grid),

•terrorist attacks, cyberattacks, or other malicious acts, including any effects of terrorism, cyberattacks, ransomware, or vandalism that may damage or disrupt information technology systems,

•changes in technology costs that impede Cleco’s ability to effectively implement new information systems or to operate and maintain current production technology,

•changes in Cleco’s strategic business plans, which could be affected by any of the factors discussed herein,

•the impact of Cleco’s credit ratings, changes in interest rates, other capital market conditions, and global market conditions on financing through the issuance of debt and/or equity securities,

•declining energy demand related to customer energy efficiency, conservation measures, or increased distributed generation,

•industry and geographic concentrations of Cleco’s counterparties, suppliers, and customers,

•deterioration in the creditworthiness of Cleco’s customers,

•volatility and illiquidity in wholesale energy markets,

•default or nonperformance on the part of any parties from whom Cleco purchases and/or sells capacity, energy, or fuel,

•Cleco Holdings’ and Cleco Power’s ability to remain in compliance with their respective debt covenants,

•the outcome of legal proceedings and other contingencies,

•changes in actuarial assumptions, interest rates, and the actual return on plan assets for Cleco’s pension and other postretirement benefit plans,

•insufficient insurance coverage, more restrictive coverage terms, increasing insurance cost, and Cleco’s ability to obtain insurance,

•Cleco’s ability to remain in compliance with the commitments made to the LPSC in connection with the Cleco Cajun Transaction and the 2016 Merger,

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

•Cleco Holdings’ dependence on the earnings, dividends, or distributions from its subsidiaries to meet its debt obligations,

•workforce factors, including aging workforce, changes in key members of management, availability of workers in a variety of skill areas, and Cleco’s ability to recruit and retain qualified employees, and

•the unpredictability of civil unrest and its direct and indirect impact on Cleco.

For more discussion of these factors and other factors that could cause actual results to differ materially from those contemplated in the Registrants’ forward-looking statements,

see Part I, Item 1A, “Risk Factors” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

All subsequent written and oral forward-looking statements attributable to the Registrants, or persons acting on their

behalf, are expressly qualified in their entirety by the factors identified above.

Any forward-looking statement is considered only as of the date of this Quarterly Report on Form 10-Q and, except as required by law, the Registrants undertake no obligation to update any forward-looking statements, whether as a result of changes in actual results, changes in assumptions, or other factors affecting such statements.

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

PART I — FINANCIAL INFORMATION

ITEM 1.  CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Cleco

These unaudited condensed consolidated financial statements should be read in conjunction with Cleco’s Consolidated Financial Statements and Notes included in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020. For more information on the basis of presentation, see “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — Basis of Presentation.”

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020
Operating revenue
Electric operations	$	351,936	$	321,956
Other operations	45,330		44,902
Gross operating revenue	397,266		366,858
Electric customer credits	(18,517)		(9,100)
Operating revenue, net	378,749		357,758
Operating expenses
Fuel used for electric generation	25,482		67,864
Purchased power	90,494		59,505
Other operations and maintenance	72,815		71,798
Depreciation and amortization	54,318		54,087
Taxes other than income taxes	11,886		14,036
Merger transaction and commitment costs	(232)		274
Total operating expenses	254,763		267,564
Operating income	123,986		90,194
Interest income	829		898
Allowance for equity funds used during construction	1,105		127
Other (expense) income, net	(3,970)		257
Interest charges
Interest charges, net	33,826		35,023
Allowance for borrowed funds used during construction	(535)		(308)
Total interest charges	33,291		34,715
Income before income taxes	88,659		56,761
Federal and state income tax expense	9,837		13,593
Net income	$	78,822	$	43,168
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020
Net income	$	78,822	$	43,168
Other comprehensive (loss) income, net of tax
Postretirement benefits (loss) gain (net of tax benefit of $148 in 2021 and tax expense of $156 in 2020)	(420)		442
Total other comprehensive (loss) income, net of tax	(420)		442
Comprehensive income, net of tax	$	78,402	$	43,610
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020
Operating revenue
Electric operations	$	718,181	$	633,113
Other operations	95,056		89,810
Gross operating revenue	813,237		722,923
Electric customer credits	(39,494)		(17,593)
Operating revenue, net	773,743		705,330
Operating expenses
Fuel used for electric generation	81,302		144,501
Purchased power	235,196		125,825
Other operations and maintenance	144,978		146,564
Depreciation and amortization	109,265		109,960
Taxes other than income taxes	33,003		30,572
Merger transaction and commitment costs	(285)		3,049
Total operating expenses	603,459		560,471
Operating income	170,284		144,859
Interest income	1,475		2,054
Allowance for equity funds used during construction	1,991		53
Other expense, net	(7,002)		(12,452)
Interest charges
Interest charges, net	67,918		70,350
Allowance for borrowed funds used during construction	(735)		(487)
Total interest charges	67,183		69,863
Income before income taxes	99,565		64,651
Federal and state income tax expense	416		15,155
Net income	$	99,149	$	49,496
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020
Net income	$	99,149	$	49,496
Other comprehensive income, net of tax
Postretirement benefits gain (net of tax expense of $74 in 2021 and $302 in 2020)	208		856
Total other comprehensive income, net of tax	208		856
Comprehensive income, net of tax	$	99,357	$	50,352
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Assets
Current assets
Cash and cash equivalents	$	78,353	$	84,976
Restricted cash and cash equivalents	2,949		4,545
Customer accounts receivable (less allowance for credit losses of $1,334 in 2021 and $2,758 in 2020)	92,686		82,511
Accounts receivable - affiliate	2,686		1,663
Other accounts receivable	34,993		32,076
Taxes receivable	5,023		—
Unbilled revenue	44,308		40,127
Fuel inventory, at average cost	164,548		109,494
Materials and supplies, at average cost	135,494		132,449
Energy risk management assets	38,724		13,081
Accumulated deferred fuel	75,295		28,194
Cash surrender value of company-/trust-owned life insurance policies	94,684		89,138
Prepayments	16,616		14,549
Regulatory assets	24,699		21,041
Other current assets	16,563		11,048
Total current assets	827,621		664,892
Property, plant, and equipment
Property, plant, and equipment	5,446,409		5,337,190
Accumulated depreciation	(821,447)		(672,271)
Net property, plant, and equipment	4,624,962		4,664,919
Construction work in progress	157,419		124,622
Total property, plant, and equipment, net	4,782,381		4,789,541
Equity investment in investee	5,572		9,072
Goodwill	1,490,797		1,490,797
Prepayments	18,337		23,405
Operating lease right of use assets	25,315		26,172
Restricted cash and cash equivalents	744		744
Note receivable	14,134		14,506
Regulatory assets	626,527		554,609
Intangible assets	98,804		111,731
Other deferred charges	51,237		40,100
Total assets	$	7,941,469	$	7,725,569
The accompanying notes are an integral part of the condensed consolidated financial statements.
(Continued on next page)

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Liabilities and member’s equity
Liabilities
Current liabilities
Short-term debt	$	160,000	$	75,000
Long-term debt and finance leases due within one year	66,718		66,682
Accounts payable	175,189		161,357
Accounts payable - affiliate	41,283		41,283
Customer deposits	60,092		58,718
Provision for rate refund	7,251		9,444
Taxes payable	32,502		7,530
Interest accrued	15,349		15,583
Energy risk management liabilities	1,161		2,453
Regulatory liabilities	44,862		23,509
Deferred compensation	13,563		13,240
Other current liabilities	54,326		49,813
Total current liabilities	672,296		524,612
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	694,046		661,376
Postretirement benefit obligations	316,330		314,653
Regulatory liabilities - deferred taxes, net	108,908		157,056
Deferred lease revenue	36,054		40,657
Intangible liabilities	21,517		24,859
Asset retirement obligations	27,404		27,986
Operating lease liabilities	22,315		23,333
Other deferred credits	24,180		28,627
Total long-term liabilities and deferred credits	1,250,754		1,278,547
Long-term debt and finance leases, net	3,162,039		3,165,387
Total liabilities	5,085,089		4,968,546
Commitments and contingencies (Note 13)
Member’s equity	2,856,380		2,757,023
Total liabilities and member’s equity	$	7,941,469	$	7,725,569
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021			2020
Operating activities
Net income	$	99,149		$	49,496
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	124,750			124,797
Provision for credit losses	2,486			4,093
Unearned compensation expense	3,749			3,219
Allowance for equity funds used during construction	(1,991)			(53)
(Gain) loss on risk management assets and liabilities, net	(48,242)			(2,534)
Deferred lease revenue	(4,603)			(4,603)
Deferred income taxes	5,425			16,120
Cash surrender value of company-/trust-owned life insurance	(5,545)			5,790
Changes in assets and liabilities
Accounts receivable	(18,826)			(10,131)
Accounts receivable, affiliate	(1,023)			(32)
Unbilled revenue	(4,181)			(6,924)
Fuel inventory and materials and supplies	(57,899)			(46,816)
Prepayments	(7,555)			(12,438)
Accounts payable	12,768			(38,532)
Customer deposits	6,286			3,699
Provision for merger commitments	(1,143)			858
Postretirement benefit obligations	1,959			3,013
Regulatory assets and liabilities, net	(17,608)			(3,580)
Deferred fuel recoveries	(48,321)			(2,137)
Other deferred accounts	(8,745)			(6,030)
Taxes accrued	19,220			17,407
Interest accrued	(234)			(2,709)
Deferred compensation	323			(1,050)
Other operating	(4,737)			4,906
Net cash provided by operating activities	45,462			95,829
Investing activities
Additions to property, plant, and equipment	(140,507)			(139,339)
Allowance for equity funds used during construction	1,991			53
Return of equity investment in investee	1,750			—
Other investing	1,091			572
Net cash used in investing activities	(135,675)			(138,714)
Financing activities
Draws on revolving credit facilities	100,000			238,000
Payments on revolving credit facilities	(15,000)			—
Repayment of long-term debt	—			(11,055)
Payment of financing costs	(2,674)			(3,471)
Other financing	(332)			(300)
Net cash provided by financing activities	81,994			223,174
Net (decrease) increase in cash, cash equivalents, restricted cash, and restricted cash equivalents	(8,219)			180,289
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	90,265		(1)	142,595
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	$	82,046	(2)	$	322,884
Supplementary cash flow information
Interest paid, net of amount capitalized	$	62,947		$	65,658
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	3,547		$	7,851
Accrued distribution from equity investment in investee	$	1,750		$	—
(1) Includes cash and cash equivalents of $84,976, current restricted cash and cash equivalents of $4,545, and non-current restricted cash and cash equivalents of $744. (2) Includes cash and cash equivalents of $78,353, current restricted cash and cash equivalents of $2,949, and non-current restricted cash and cash equivalents of $744.
The accompanying notes are an integral part of the condensed consolidated financial statements.

14

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited)
(THOUSANDS)	MEMBERSHIP INTEREST		RETAINED EARNINGS		AOCI		TOTAL MEMBER’S EQUITY
Balances, March 31, 2020	$	2,454,276	$	212,571	$	(17,099)	$	2,649,748
Net income	—		43,168		—		43,168
Other comprehensive income, net of tax	—		—		442		442
Balances, June 30, 2020	$	2,454,276	$	255,739	$	(16,657)	$	2,693,358
Balances, March 31, 2021	$	2,454,276	$	348,870	$	(25,168)	$	2,777,978
Net income	—		78,822		—		78,822
Other comprehensive loss, net of tax	—		—		(420)		(420)
Balances, June 30, 2021	$	2,454,276	$	427,692	$	(25,588)	$	2,856,380
Balances, Dec. 31, 2019	$	2,454,276	$	206,243	$	(17,513)	$	2,643,006
Net income	—		49,496		—		49,496
Other comprehensive income, net of tax	—		—		856		856
Balances, June 30, 2020	$	2,454,276	$	255,739	$	(16,657)	$	2,693,358
Balances, Dec. 31, 2020	$	2,454,276	$	328,543	$	(25,796)	$	2,757,023
Net income	—		99,149		—		99,149
Other comprehensive income, net of tax	—		—		208		208
Balances, June 30, 2021	$	2,454,276	$	427,692	$	(25,588)	$	2,856,380
The accompanying notes are an integral part of the condensed consolidated financial statements.

15

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

ITEM 1.  CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Cleco Power

These unaudited condensed consolidated financial statements should be read in conjunction with Cleco Power’s Consolidated Financial Statements and Notes included in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020. For more information on the basis of presentation, see “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — Basis of Presentation.”

16

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020
Operating revenue
Electric operations	$	262,948	$	239,643
Other operations	16,269		15,904
Affiliate revenue	1,224		1,240
Gross operating revenue	280,441		256,787
Electric customer credits	(18,762)		(9,100)
Operating revenue, net	261,679		247,687
Operating expenses
Fuel used for electric generation	68,633		64,064
Purchased power	34,255		19,179
Other operations and maintenance	52,160		54,667
Depreciation and amortization	40,933		41,596
Taxes other than income taxes	7,314		9,448
Total operating expenses	203,295		188,954
Operating income	58,384		58,733
Interest income	825		755
Allowance for equity funds used during construction	1,105		127
Other expense, net	(5,700)		(3,423)
Interest charges
Interest charges, net	18,772		18,911
Allowance for borrowed funds used during construction	(535)		(308)
Total interest charges	18,237		18,603
Income before income taxes	36,377		37,589
Federal and state income tax expense	8,956		9,356
Net income	$	27,421	$	28,233
The accompanying notes are an integral part of the condensed consolidated financial statements.

17

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020
Net income	$	27,421	$	28,233
Other comprehensive income, net of tax
Postretirement benefits gain (net of tax expense of $101 in 2021 and $148 in 2020)	287		419
Amortization of interest rate derivatives to earnings (net of tax expense of $22 in both 2021 and 2020)	64		64
Total other comprehensive income, net of tax	351		483
Comprehensive income, net of tax	$	27,772	$	28,716
The accompanying notes are an integral part of the condensed consolidated financial statements.

18

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020
Operating revenue
Electric operations	$	530,107	$	464,073
Other operations	34,895		31,668
Affiliate revenue	2,879		2,346
Gross operating revenue	567,881		498,087
Electric customer credits	(39,738)		(17,440)
Operating revenue, net	528,143		480,647
Operating expenses
Fuel used for electric generation	113,843		125,129
Purchased power	113,288		42,641
Other operations and maintenance	105,726		111,608
Depreciation and amortization	83,009		85,273
Taxes other than income taxes	23,816		21,725
Total operating expenses	439,682		386,376
Operating income	88,461		94,271
Interest income	1,468		1,709
Allowance for equity funds used during construction	1,991		53
Other expense, net	(9,958)		(6,091)
Interest charges
Interest charges, net	37,618		37,671
Allowance for borrowed funds used during construction	(735)		(487)
Total interest charges	36,883		37,184
Income before income taxes	45,079		52,758
Federal and state income tax (benefit) expense	(767)		12,694
Net income	$	45,846	$	40,064
The accompanying notes are an integral part of the condensed consolidated financial statements.

19

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020
Net income	$	45,846	$	40,064
Other comprehensive income, net of tax
Postretirement benefits gain (net of tax expense of $263 in 2021 and $299 in 2020)	745		845
Amortization of interest rate derivatives to earnings (net of tax expense of $45 in both 2021 and 2020)	128		128
Total other comprehensive income, net of tax	873		973
Comprehensive income, net of tax	$	46,719	$	41,037
The accompanying notes are an integral part of the condensed consolidated financial statements.

20

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Assets
Utility plant and equipment
Property, plant, and equipment	$	5,915,689	$	5,824,378
Accumulated depreciation	(2,190,690)		(2,067,362)
Net property, plant, and equipment	3,724,999		3,757,016
Construction work in progress	146,232		110,613
Total utility plant and equipment, net	3,871,231		3,867,629
Current assets
Cash and cash equivalents	20,767		24,846
Restricted cash and cash equivalents	2,949		4,545
Customer accounts receivable (less allowance for credit losses of $1,334 in 2021 and $2,758 in 2020)	49,863		43,852
Accounts receivable - affiliate	13,026		14,605
Other accounts receivable	27,715		27,535
Unbilled revenue	44,308		40,127
Fuel inventory, at average cost	119,379		63,234
Materials and supplies, at average cost	108,022		105,340
Energy risk management assets	6,867		4,337
Accumulated deferred fuel	75,295		28,194
Cash surrender value of company-owned life insurance policies	16,230		16,184
Prepayments	7,189		7,163
Regulatory assets	16,964		13,305
Other current assets	5,551		830
Total current assets	514,125		394,097
Equity investment in investee	5,572		9,072
Prepayments	1,370		1,496
Operating lease right of use assets	25,263		26,006
Note receivable	14,134		14,506
Regulatory assets	491,487		414,535
Other deferred charges	24,239		38,806
Total assets	$	4,947,421	$	4,766,147
The accompanying notes are an integral part of the condensed consolidated financial statements.
(Continued on next page)

21

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Liabilities and member’s equity
Member’s equity	$	1,854,598	$	1,807,879
Long-term debt and finance leases, net	1,502,155		1,502,257
Total capitalization	3,356,753		3,310,136
Current liabilities
Short-term debt	160,000		75,000
Long-term debt and finance leases due within one year	718		682
Accounts payable	135,352		106,089
Accounts payable - affiliate	70,437		72,068
Customer deposits	60,092		58,718
Provision for rate refund	7,251		8,630
Taxes payable	35,568		4,778
Interest accrued	5,108		5,357
Energy risk management liabilities	877		1,121
Regulatory liabilities	44,862		23,509
Other current liabilities	23,475		24,754
Total current liabilities	543,740		380,706
Commitments and contingencies (Note 13)
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	653,655		634,598
Postretirement benefit obligations	233,265		230,825
Regulatory liabilities - deferred taxes, net	108,908		157,056
Asset retirement obligations	11,529		11,364
Operating lease liabilities	22,282		23,295
Other deferred credits	17,289		18,167
Total long-term liabilities and deferred credits	1,046,928		1,075,305
Total liabilities and member’s equity	$	4,947,421	$	4,766,147
The accompanying notes are an integral part of the condensed consolidated financial statements.

22

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021			2020
Operating activities
Net income	$	45,846		$	40,064
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	85,844			88,034
Provision for credit losses	2,486			3,705
Unearned compensation expense	1,063			730
Allowance for equity funds used during construction	(1,991)			(53)
Deferred income taxes	(8,424)			6,091
Cash surrender value of company-owned life insurance	(46)			1,445
Changes in assets and liabilities
Accounts receivable	(11,775)			(15,462)
Accounts receivable - affiliate	3,368			2,573
Unbilled revenue	(4,181)			(6,924)
Fuel inventory and materials and supplies	(58,627)			(35,639)
Accounts payable	30,625			(30,242)
Accounts payable - affiliate	(1,763)			(3,149)
Customer deposits	6,286			3,699
Provision for merger commitments	(643)			(1,455)
Postretirement benefit obligations	1,661			1,800
Regulatory assets and liabilities, net	(18,602)			(4,574)
Deferred fuel recoveries	(48,321)			(2,137)
Other deferred accounts	(4,898)			(5,778)
Taxes accrued	30,062			23,517
Interest accrued	(249)			(2,056)
Other operating	(7,196)			2,299
Net cash provided by operating activities	40,525			66,488
Investing activities
Additions to property, plant, and equipment	(134,185)			(132,578)
Allowance for equity funds used during construction	1,991			53
Return of equity investment in investee	1,750			—
Other investing	1,091			572
Net cash used in investing activities	(129,353)			(131,953)
Financing activities
Draws on revolving credit facility	100,000			150,000
Payments on revolving credit facility	(15,000)			—
Repayment of long-term debt	—			(11,055)
Payment of financing costs	(1,515)			(1,123)
Other financing	(332)			(300)
Net cash provided by financing activities	83,153			137,522
Net (decrease) increase in cash, cash equivalents, restricted cash, and restricted cash equivalents	(5,675)			72,057
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	29,391		(1)	80,952
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	$	23,716	(2)	$	153,009
Supplementary cash flow information
Interest paid, net of amount capitalized	$	33,973		$	33,711
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	2,814		$	7,581
Accrued distribution from equity investment in investee	$	1,750		$	—
(1) Includes cash and cash equivalents of $24,846 and current restricted cash and cash equivalents of $4,545. (2) Includes cash and cash equivalents of $20,767 and current restricted cash and cash equivalents of $2,949.
The accompanying notes are an integral part of the condensed consolidated financial statements.

23

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited)
(THOUSANDS)	MEMBER’S EQUITY		AOCI		TOTAL  MEMBER’S EQUITY
Balances, March 31, 2020	$	1,747,808	$	(22,095)	$	1,725,713
Net income	28,233		—		28,233
Other comprehensive income, net of tax	—		483		483
Balances, June 30, 2020	$	1,776,041	$	(21,612)	$	1,754,429
Balances, March 31, 2021	$	1,851,057	$	(24,231)	$	1,826,826
Net income	27,421		—		27,421
Other comprehensive income, net of tax	—		351		351
Balances, June 30, 2021	$	1,878,478	$	(23,880)	$	1,854,598
Balances, Dec. 31, 2019	$	1,735,977	$	(22,585)	$	1,713,392
Net income	40,064		—		40,064
Other comprehensive income, net of tax	—		973		973
Balances, June 30, 2020	$	1,776,041	$	(21,612)	$	1,754,429
Balances, Dec. 31, 2020	$	1,832,632	$	(24,753)	$	1,807,879
Net income	45,846		—		45,846
Other comprehensive income, net of tax	—		873		873
Balances, June 30, 2021	$	1,878,478	$	(23,880)	$	1,854,598
The accompanying notes are an integral part of the condensed consolidated financial statements.

24

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

Index to Applicable Notes to the Unaudited Condensed Consolidated Financial Statements of Registrants
Note 1	Summary of Significant Accounting Policies	Cleco and Cleco Power
Note 2	Recent Authoritative Guidance	Cleco and Cleco Power
Note 3	Leases	Cleco and Cleco Power
Note 4	Revenue Recognition	Cleco and Cleco Power
Note 5	Regulatory Assets and Liabilities	Cleco and Cleco Power
Note 6	Fair Value Accounting	Cleco and Cleco Power
Note 7	Debt	Cleco and Cleco Power
Note 8	Pension Plan and Employee Benefits	Cleco and Cleco Power
Note 9	Income Taxes	Cleco and Cleco Power
Note 10	Disclosures about Segments	Cleco
Note 11	Regulation and Rates	Cleco and Cleco Power
Note 12	Variable Interest Entities	Cleco and Cleco Power
Note 13	Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	Cleco and Cleco Power
Note 14	Affiliate Transactions	Cleco and Cleco Power
Note 15	Intangible Assets and Liabilities	Cleco and Cleco Power
Note 16	Accumulated Other Comprehensive Loss	Cleco and Cleco Power
Note 17	Storm Restoration	Cleco and Cleco Power

Notes to the Unaudited Condensed Consolidated Financial Statements

Note 1 — Summary of Significant Accounting Policies

COVID-19 Impacts

In March 2020, WHO declared the outbreak of COVID-19 to be a global pandemic, and the U.S. declared a national emergency. In response to these declarations and the rapid spread of COVID-19, federal, state and local governments imposed varying degrees of restrictions on business and social activities to contain COVID-19, including quarantine and “stay-at-home” orders and directives in Cleco’s service territory. State and local authorities also subsequently implemented multistep policies to reopen various sectors of the economy such as retail establishments, health and personal care businesses, and restaurants, among others. During March and April 2021, due to the reduction in new COVID-19 cases and hospitalizations and the availability of COVID-19 vaccines, the governor of the state of Louisiana reduced restrictions that were previously in effect, eased capacity limits on businesses and social gatherings, and revoked the mandatory, state-wide mask mandate. However, effective August 4, 2021, the state-wide mask mandate was reinstated due to a surge in COVID-19 cases.

The COVID-19 pandemic may worsen in the U.S. during the upcoming months, which may cause federal, state, and local governments to reconsider restrictions on business and social activities. In the event governments reinstate or increase restrictions, the reopening of the economy may be further curtailed.

Cleco has modified some of its business operations, as these restrictions have significantly impacted many sectors of the economy. Impacts include record levels of unemployment, with businesses, nonprofit organizations, and governmental entities modifying, curtailing, or ceasing normal operations. Cleco is monitoring the ongoing COVID-19 pandemic and continues to adjust certain business practices to conform to government restrictions and best practices encouraged by the CDC, WHO, and other governmental and regulatory authorities.

Cleco cannot predict the full impact that COVID-19, or the significant disruption and volatility currently being experienced in the markets, will have on its business, cash flows, liquidity, financial condition, and results of operations at this time, due to numerous uncertainties. The ultimate impacts will depend on future developments, including, among others, the ultimate geographic spread of COVID-19, the consequences of governmental and other measures designed to prevent the spread of COVID-19, the availability, timely distribution and acceptance of effective treatments and vaccines, the duration of the pandemic, actions taken by governmental authorities, customers, suppliers and other third parties, workforce availability, and the timing and extent to which normal economic and operating conditions resume.

Principles of Consolidation

The accompanying condensed consolidated financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Basis of Presentation

The condensed consolidated financial statements of Cleco and Cleco Power have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these condensed consolidated financial statements do not include all of the information and notes required by GAAP for annual financial statements. The year-end condensed consolidated balance sheet data was derived from audited financial statements. Because the interim condensed consolidated financial statements and the accompanying notes do not include all of the information and notes required by GAAP for annual financial statements, the condensed consolidated financial statements and other information included in this Quarterly Report on Form 10-Q should be read in conjunction with the consolidated financial statements and accompanying notes in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

25

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

These condensed consolidated financial statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly state the financial position and results of operations of Cleco and Cleco Power. Amounts reported in Cleco and Cleco Power’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, discrete income tax items, and other factors.

In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates. For information on recent authoritative guidance and its effect on financial results, see Note 2 — “Recent Authoritative Guidance.”

Restricted Cash and Cash Equivalents

Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general corporate purposes.

Cleco and Cleco Power’s restricted cash and cash equivalents consisted of the following:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current
Cleco Katrina/Rita’s storm recovery bonds	$	1,673	$	2,626
Cleco Power’s charitable contributions	1,078		1,718
Cleco Power’s rate credit escrow	198		201
Total current	2,949		4,545
Non-current
Diversified Lands’ mitigation escrow	22		22
Cleco Cajun’s defense fund	722		722
Total non-current	744		744
Total restricted cash and cash equivalents	$	3,693	$	5,289

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current
Cleco Katrina/Rita’s storm recovery bonds	$	1,673	$	2,626
Charitable contributions	1,078		1,718
Rate credit escrow	198		201
Total restricted cash and cash equivalents	$	2,949	$	4,545

Prior to the repayment of the storm recovery bonds in March 2020, Cleco Katrina/Rita had the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash was collected, it was restricted for payment of administrative fees, interest, and principal on the storm recovery bonds. The remaining $1.7 million of restricted cash relating to Cleco Katrina/Rita at June 30, 2021, will be used to benefit retail customers in a manner and timing as approved by the LPSC.

Reserves for Credit Losses

Customer accounts receivable are recorded at the invoiced amount and do not bear interest. Customer accounts receivable are generally considered to become past due 20 days after the billing date. Cleco recognizes write-offs within the allowance for credit losses once all recovery methods have been exhausted. It is the policy of management to review accounts receivable and unbilled revenue monthly using a reserve matrix based on historical bad debt write-offs, as well as current and forecasted economic conditions, to establish a credit loss estimate. Management’s historical credit loss analysis included periods of economic recessions, natural disasters, and temporary changes to collection policies. Due to the critical necessity of electricity, none of these past events have significantly impacted Cleco’s credit loss rates.

Although Cleco’s service territory experienced a recent decline in the economy in 2020 and 2021 primarily related to the COVID-19 pandemic and weather-related events, the economic outlook at June 30, 2021, was still within range of its historical credit loss analysis.

The tables below present the changes in the allowance for credit losses by receivable for Cleco and Cleco Power:

Cleco
			FOR THE THREE MONTHS  ENDED JUNE 30, 2021						FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	ACCOUNTS RECEIVABLE		OTHER*		TOTAL		ACCOUNTS RECEIVABLE		OTHER*		TOTAL
Balances, beginning of period	$	2,040	$	1,638	$	3,678	$	2,758	$	1,638	$	4,396
Current period provision	616		—		616		2,490		—		2,490
Charge-offs	(1,583)		—		(1,583)		(4,442)		—		(4,442)
Recovery	261		—		261		528		—		528
Balances, June 30, 2021	$	1,334	$	1,638	$	2,972	$	1,334	$	1,638	$	2,972

* Loan held at Diversified Lands that was fully reserved for at June 30, 2021.

26

CLECO
CLECO POWER	2021 2ND QUARTER FORM 10-Q

			FOR THE THREE MONTHS  ENDED JUNE 30, 2020						FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE		OTHER*		TOTAL		ACCOUNTS RECEIVABLE		OTHER*		TOTAL
Balances, beginning of period	$	2,123	$	1,638	$	3,761	$	3,005	$	1,250	$	4,255
CECL adoption	—		—		—		71		—		71
Current period provision	1,137		—		1,137		3,634		388		4,022
Charge-offs	—		—		—		(4,091)		—		(4,091)
Recovery	226		—		226		867		—		867
Balances, June 30, 2020	$	3,486	$	1,638	$	5,124	$	3,486	$	1,638	$	5,124

* Loan held at Diversified Lands that was fully reserved for at June 30, 2020.

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2021		FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	ACCOUNTS RECEIVABLE
Balances, beginning of period	$	2,040	$	2,758
Current period provision	616		2,490
Charge-offs	(1,583)		(4,442)
Recovery	261		528
Balances, June 30, 2021	$	1,334	$	1,334

	FOR THE THREE MONTHS ENDED JUNE 30, 2020		FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE
Balances, beginning of period	$	2,123	$	3,005
CECL adoption	—		71
Current period provision	1,137		3,634
Charge-offs	—		(4,091)
Recovery	226		867
Balances, June 30, 2020	$	3,486	$	3,486

Note 2 — Recent Authoritative Guidance

In March 2020, FASB issued optional guidance for a limited period of time that applies to entities meeting certain criteria for the contract modifications or hedging relationships that are referencing LIBOR or another reference rate expected to be discontinued due to reference rate reform. The guidance includes a general principal that permits an entity to consider contract modifications due to reference rate reform to be an event that does not require contract remeasurement at the modification date or reassessment of a previous accounting determination. The optional guidance may be applied from March 12, 2020, through December 31, 2022. Management has identified contracts with reference rates that will be discontinued, primarily related to long-term debt obligations. In the second quarter of 2021, certain debt contracts were amended to include fallback provisions that provide substitute reference rates upon the discontinuance of LIBOR, among other amendments. Management will continue to modify

contracts to include similar fallback language and expects to apply this guidance on an ongoing basis. Management does not expect this guidance to have a significant impact on the Registrants’ results of operations, financial condition, or cash flows.

In December 2019, FASB amended the guidance for accounting for income taxes. The amendments simplify the accounting for income taxes by removing certain exceptions to general principles included in the accounting guidance. Effective January 1, 2021, Cleco adopted the amended accounting guidance. Adoption of this guidance did not materially impact the Registrants’ results of operations, financial condition, or cash flows.

Note 3 — Leases

Cleco maintains operating and finance leases in its ordinary course of business activities.

Cottonwood Sale Leaseback Agreement

Upon closing the Cleco Cajun Transaction, the Cottonwood Sale Leaseback was executed. Under the terms of the lease, NRG Energy will operate the Cottonwood Plant, incur all costs, and receive all revenues from the operations of the plant. Cottonwood Energy will receive fixed lease payments of $40.0 million per year and variable lease payments for LTSA costs and property taxes paid by NRG Energy on behalf of Cleco. Cleco may terminate the lease contract under specific circumstances stated in the lease contract. The residual value under the Cottonwood Sale Leaseback is expected to be recovered through sales of power generation from the plant. The residual value of the Cottonwood Plant has been determined using the plant’s estimated economic life.

Cleco Cajun is Cleco’s only entity with lessor arrangements. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback is included in Other operations within Cleco’s Condensed Consolidated Statement of Income. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback for the three and six months ended June 30, 2021, and 2020, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE. 30,
(THOUSANDS)	2021		2020		2021		2020
Fixed payments	$	10,000	$	10,000	$	20,000	$	20,000
Variable payments	5,010		5,194		10,475		10,760
Amortization of deferred lease liability*	2,301		2,301		4,603		4,603
Total lease income	$	17,311	$	17,495	$	35,078	$	35,363

* Consists of amortization of the deferred lease revenue resulting from the fair value of the lease between Cottonwood Energy and a special-purpose entity that is a subsidiary of NRG Energy.

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Note 4 — Revenue Recognition

Operating revenue, net for the three and six months ended June 30, 2021, and 2020, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	105,315		$	—		$	—		$	—	$	105,315
Commercial (1)	68,392			—			—			—		68,392
Industrial (1)	37,385			—			—			—		37,385
Other retail (1)	3,876			—			—			—		3,876
Electric customer credits	(19,054)			—			—			—		(19,054)
Total retail revenue	195,914			—			—			—		195,914
Wholesale, net	46,216		(1)	91,407			(2,420)		(2)			135,203
Transmission, net	13,313		(3)	13,573		(4)	—			(1,595)		25,291
Other	3,249			—			—			—		3,249
Affiliate (5)	1,224			—			26,120			(27,344)		—
Total revenue from contracts with customers	259,916			104,980			23,700			(28,939)		359,657
Revenue unrelated to contracts with customers
Other	1,763		(6)	17,326		(7)	1			2		19,092
Total revenue unrelated to contracts with customers	1,763			17,326			1			2		19,092
Operating revenue, net	$	261,679		$	122,306		$	23,701		$	(28,937)	$	378,749

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $(0.3) million of electric customer credits.

(4) Includes $(0.2) million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $15.0 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization.

	FOR THE THREE MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	97,973		$	—		$	—		$	—	$	97,973
Commercial (1)	61,575			—			—			—		61,575
Industrial (1)	29,208			—			—			—		29,208
Other retail (1)	3,341			—			—			—		3,341
Electric customer credits	(8,423)			—			—			—		(8,423)
Total retail revenue	183,674			—			—			—		183,674
Wholesale, net	45,694		(1)	84,733			(2,420)		(2)	—		128,007
Transmission, net	11,625		(3)	13,131			—			(1,639)		23,117
Other	3,601			—			—			—		3,601
Affiliate (4)	1,240			43			29,138			(30,421)		—
Total revenue from contracts with customers	245,834			97,907			26,718			(32,060)		338,399
Revenue unrelated to contracts with customers
Other	1,853		(5)	17,505		(6)	1			—		19,359
Total revenue unrelated to contracts with customers	1,853			17,505			1			—		19,359
Operating revenue, net	$	247,687		$	115,412		$	26,719		$	(32,060)	$	357,758

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $0.7 million of electric customer credits.

(4) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(5) Realized gains associated with FTRs.

(6) Includes $15.2 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization.

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	FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	200,396		$	—		$	—		$	—	$	200,396
Commercial (1)	131,418			—			—			—		131,418
Industrial (1)	74,051			—			—			—		74,051
Other retail (1)	7,446			—			—			—		7,446
Electric customer credits	(40,030)			—			—			—		(40,030)
Total retail revenue	373,281			—			—			—		373,281
Wholesale, net	107,938		(1)	192,914			(4,840)		(2)	—		296,012
Transmission, net	27,295		(3)	28,830		(4)	—			(3,535)		52,590
Other	7,891			—			—			—		7,891
Affiliate (5)	2,879			—			53,276			(56,155)		—
Total revenue from contracts with customers	519,284			221,744			48,436			(59,690)		729,774
Revenue unrelated to contracts with customers
Other	8,859		(6)	35,108		(7)	2			—		43,969
Total revenue unrelated to contracts with customers	8,859			35,108			2			—		43,969
Operating revenue, net	$	528,143		$	256,852		$	48,438		$	(59,690)	$	773,743

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $(0.3) million of electric customer credits.

(4) Includes $(0.2) million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $30.5 million in lease revenue related to the Cottonwood Sale Leaseback and $4.6 million of deferred lease revenue amortization.

	FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	179,544		$	—		$	—		$	—	$	179,544
Commercial (1)	122,685			—			—			—		122,685
Industrial (1)	61,418			—			—			—		61,418
Other retail (1)	6,802			—			—			—		6,802
Surcharge	2,443			—			—			—		2,443
Electric customer credits	(16,763)			—			—			—		(16,763)
Total retail revenue	356,129			—			—			—		356,129
Wholesale, net	87,923		(1)	173,880			(4,840)		(2)	—		256,963
Transmission, net	23,694		(3)	26,062		(4)	—			(3,456)		46,300
Other	7,296			—			—			—		7,296
Affiliate (5)	2,346			204			58,415			(60,965)		—
Total revenue from contracts with customers	477,388			200,146			53,575			(64,421)		666,688
Revenue unrelated to contracts with customers
Other	3,259		(6)	35,382		(7)	1			—		38,642
Total revenue unrelated to contracts with customers	3,259			35,382			1			—		38,642
Operating revenue, net	$	480,647		$	235,528		$	53,576		$	(64,421)	$	705,330

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $0.7 million of electric customer credits.

(4) Includes $0.2 million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $30.8 million in lease revenue related to the Cottonwood Sale Leaseback and $4.6 million of deferred lease revenue amortization.

Cleco and Cleco Power have unsatisfied performance obligations under contracts with cooperatives and municipalities with durations ranging between 1 and 14 years that primarily relate to stand-ready obligations as part of fixed capacity minimums. At June 30, 2021, Cleco and Cleco Power had $68.2 million of unsatisfied fixed performance obligations that will be recognized as revenue over the term of such contracts as the stand-ready obligation to provide energy is provided.

Note 5 — Regulatory Assets and Liabilities

Cleco Power capitalizes or defers certain costs for recovery from customers and recognizes a liability for amounts expected to be returned to customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered or refunded through the ratemaking process.

Under the current regulatory environment, Cleco Power believes these regulatory assets will be fully recoverable; however, if in the future, as a result of regulatory changes or

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competition, Cleco Power’s ability to recover these regulatory assets would no longer be probable, then to the extent that such regulatory assets were determined not to be recoverable, Cleco Power would be required to write-down such assets. In addition, potential deregulation of the industry or possible future changes in the method of rate regulation of Cleco Power could require discontinuance of the application of the authoritative guidance on regulated operations.

The following table summarizes Cleco Power’s regulatory assets and liabilities:

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Regulatory assets
Acadia Unit 1 acquisition costs	$	1,966	$	2,019
Accumulated deferred fuel	75,295		28,194
AFUDC equity gross-up *	68,122		69,670
Affordability study	13,644		—
AMI deferred revenue requirement	2,318		2,591
AROs	7,202		5,488
Coughlin transaction costs	861		876
COVID-19 executive order	2,953		2,953
Deferred storm restoration costs -   Hurricane Delta	17,802		17,051
Deferred storm restoration costs -   Hurricane Laura	56,412		54,406
Deferred storm restoration costs -   Hurricane Zeta	3,494		3,493
Deferred storm restoration costs -   Winter Storms Uri & Viola	1,980		—
Dolet Hills Power Station closure costs	91,479		48,982
Dolet Hills Mine closure costs	13,910		—
Emergency declarations	—		270
Energy efficiency	2,350		2,820
Financing costs	7,011		7,184
Interest costs	3,583		3,708
Madison Unit 3 property taxes	4,181		—
Non-service cost of postretirement benefits	10,881		9,901
Other	13,040		4,229
Postretirement costs	155,067		165,437
Production operations and maintenance expenses	2,664		4,058
Rodemacher Unit 2 deferred costs	4,115		1,333
St. Mary Clean Energy Center	6,959		3,479
Training costs	6,007		6,085
Tree trimming costs	10,450		11,807
Total regulatory assets	583,746		456,034
Regulatory liabilities
AFUDC	(5,359)		(4,218)
Corporate franchise tax, net	—		(763)
Deferred taxes, net	(148,411)		(175,584)
Total regulatory liabilities	(153,770)		(180,565)
Total regulatory assets, net	$	429,976	$	275,469
* Represents regulatory assets for past expenditures that were not earning a return on investment at June 30, 2021, and December 31, 2020, respectively. All other assets are earning a return on investment.

The following table summarizes Cleco’s net regulatory assets and liabilities:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Total Cleco Power regulatory assets, net	$	429,976	$	275,469
2016 Merger adjustments *
Fair value of long-term debt	115,852		119,553
Postretirement costs	14,418		15,411
Financing costs	7,419		7,592
Debt issuance costs	5,086		5,254
Total Cleco regulatory assets, net	$	572,751	$	423,279

* Cleco regulatory assets include acquisition accounting adjustments as a result of the 2016 Merger.

Accumulated Deferred Fuel

In February 2021, Winter Storms Uri and Viola moved through Louisiana causing substantial damage to Cleco’s distribution assets, electricity generation supply shortages, natural gas supply shortages, and increases in wholesale prices of natural gas in the United States, primarily due to prolonged freezing temperatures. Incremental fuel and purchased power costs were incurred as a result of the winter storms. On March 29, 2021, Cleco Power received approval from the LPSC to recover $50.0 million of these costs through Cleco Power’s FAC over a period of 12 months beginning in May 2021. For more information about the incremental fuel and purchased power costs related to Winter Storms Uri and Viola, see Note 17 — “Storm Restoration — Winter Storms Uri and Viola.”

Affordability Study

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan. As a result, Cleco Power was allowed to establish a regulatory asset of $13.6 million related to outside consulting fees for the assessment of Cleco Power’s practices and assistance in the identification of potential cost savings opportunities, while maintaining superior levels of employee safety, reliability, customer service, environmental stewardship, community involvement, and regulatory transparency. The regulatory asset is being amortized over 10 years beginning July 1, 2021.

Deferred Storm Restoration Costs — Winter Storms

In February 2021, Cleco Power’s service territory experienced extreme and unprecedented winter weather.

On February 14, 2021, Winter Storm Uri reached Louisiana resulting in power outages for approximately 11,000 of Cleco Power’s electric customers located primarily in south Louisiana.

On February 17, 2021, Winter Storm Viola reached Louisiana resulting in power outages for approximately 43,000 of Cleco Power’s electric customers located primarily in central and south Louisiana.

On March 17, 2021, the LPSC approved utilities establishing a regulatory asset to track and defer non-capital expenses associated with these winter storms. For more information about Winter Storms Uri and Viola, see Note 17 — “Storm Restoration — Winter Storms Uri and Viola.”

Dolet Hills Mine Closure Cost

On March 17, 2021, the LPSC approved the establishment of a regulatory asset for lignite costs that exceeded $150 per ton that would otherwise be billed through Cleco Power’s FAC and any reasonable incremental third-party professional costs

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related to the closure of the mine. At June 30, 2021, Cleco Power had a regulatory asset of $13.9 million for these mine-related incurred costs.

Madison Unit 3 Property Taxes

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan. As a result, beginning July 1, 2022, Cleco Power will be allowed to recover property taxes paid for Madison Unit 3, including a carrying charge at Cleco Power’s weighted average cost of capital, grossed up for taxes. At June 30, 2021, Cleco Power recorded a regulatory asset of $4.2 million for the accrued 2021 Madison Unit 3 property taxes. The amount included in the cost recovery mechanism each year will amortize over 12 months.

Other

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan resulting in Cleco Power establishing several regulatory assets. Cleco Power was allowed to establish a regulatory asset to recover the undercollection of revenues related to the Northlake Transmission Agreement. At June 30, 2021, Cleco Power had $3.5 million recorded for this regulatory asset, which is being amortized over 12 months beginning July 1, 2021. In addition, the LPSC approved recovery of other previously deferred costs totaling $4.1 million which are being amortized over four years beginning July 1, 2021. These costs are primarily associated with Cleco Power’s recently approved base rate case.

In June 2017 and prior to the approval of Cleco Power’s new retail rate plan, the LPSC approved the establishment of a regulatory asset upon the completion of the Coughlin Pipeline project for the revenue requirement associated with the project until Cleco Power’s new retail rate plan was approved. At June 30, 2021, Cleco Power had a regulatory asset of $5.4 million related to the deferred revenue associated with the Coughlin Pipeline project. As approved by the LPSC in Cleco Power’s new rate plan, the regulatory asset is being amortized over four years beginning July 1, 2021.

St. Mary Clean Energy Center

At June 30, 2021, Cleco Power had a regulatory asset of $7.0 million for revenue requirements related to the St. Mary Clean Energy Center. As approved by the LPSC in Cleco Power’s new retail rate plan, the regulatory asset is being amortized over four years beginning July 1, 2021.

Note 6 — Fair Value Accounting

The amounts reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021, and December 31, 2020, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, short-term debt, and accounts payable approximate fair value because of their short-term nature. Cleco applies the provisions of the fair value measurement standard to its non-recurring, non-financial measurements including business combinations, as well as impairment related to goodwill and other long-lived assets.

The following tables summarize the carrying value and estimated market value of Cleco and Cleco Power’s financial instruments not measured at fair value on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets:

Cleco
	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	3,226,952	$	3,509,555	$	3,230,500	$	3,541,349

* The carrying value of long-term debt does not include deferred issuance costs of $12.8 million at
June 30, 2021, and $13.4 million at December 31, 2020.

Cleco Power
	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,495,101	$	1,772,243	$	1,494,947	$	1,794,799

* The carrying value of long-term debt does not include deferred issuance costs of $6.9 million at
June 30, 2021, and $7.0 million at December 31, 2020.

In order to fund capital requirements, Cleco issues fixed and variable rate long-term debt with various tenors. The fair value of this class fluctuates as the market interest rates for fixed and variable rate debt with similar tenors and credit ratings change. The fair value of the debt could also change from period to period due to changes in the credit rating of the Cleco entity by which the debt was issued. The fair value of long-term debt is classified as Level 2 in the fair value hierarchy.

Fair Value Measurements and Disclosures

Cleco classifies assets and liabilities that are measured at their fair value according to three different levels depending on the inputs used in determining fair value. Cleco elects not to designate derivatives as cash flow or fair value hedges, as allowed by accounting guidance. Cleco utilizes a mark-to-market approach recognizing changes in the fair value of FTRs and other commodity derivatives at Cleco Cajun in earnings and changes in the fair value of FTRs at Cleco Power as a component of deferred fuel assets and liabilities. Cleco utilizes different valuation techniques for fair value measurements under a fair value hierarchy. Assets and liabilities classified as Level 1 under the hierarchy utilize observable inputs that reflect quotable prices in active markets. Assets and liabilities classified as Level 2 are measured through proxy inputs of similar index or composite pricing. Assets and liabilities classified as Level 3 under the hierarchy are valued based on unobservable inputs, such as internally generated valuation models or valuations obtained in inactive markets where there is no readily available information. Cleco has consistently applied the Level 2 and Level 3 fair value techniques from fiscal period to fiscal period. Significant increases or decreases in any of those inputs in isolation would result in a significantly different fair value measurement. The assets and liabilities reported at fair value are grouped into classes based on the underlying nature and risks associated with the individual asset or liability.

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The following tables disclose for Cleco and Cleco Power the fair value of financial assets and liabilities measured on a recurring basis:

Cleco
	FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS)	AT JUNE 30, 2021		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2020		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset description
Institutional money market funds	$	77,105	$	—	$	77,105	$	—	$	86,001	$	—	$	86,001	$	—
FTRs	8,662		—		—		8,662		4,805		—		—		4,805
Other commodity derivatives*	55,834		—		55,834		—		8,599		—		8,599		—
Total assets	$	141,601	$	—	$	132,939	$	8,662	$	99,405	$	—	$	94,600	$	4,805
Liability description
FTRs	$	1,161	$	—	$	—	$	1,161	$	1,625	$	—	$	—	$	1,625
Other commodity derivatives*	—		—		—		—		1,612		—		1,612		—
Total liabilities	$	1,161	$	—	$	—	$	1,161	$	3,237	$	—	$	1,612	$	1,625

* Other commodity derivatives include fixed price physical forwards and swap transactions.

Cleco Power
	FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS)	AT JUNE 30, 2021		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2020		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset description
Institutional money market funds	$	19,061	$	—	$	19,061	$	—	$	25,357	$	—	$	25,357	$	—
FTRs	6,867		—		—		6,867		4,337		—		—		4,337
Total assets	$	25,928	$	—	$	19,061	$	6,867	$	29,694	$	—	$	25,357	$	4,337
Liability description
FTRs	$	877	$	—	$	—	$	877	$	1,121	$	—	$	—	$	1,121
Total liabilities	$	877	$	—	$	—	$	877	$	1,121	$	—	$	—	$	1,121

The following tables summarize the net changes in the net fair value of FTR assets and liabilities classified as Level 3 in the fair value hierarchy for Cleco and Cleco Power:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Beginning balance	$	1,023	$	1,096	$	3,180	$	5,778
Unrealized (losses) gains*	(1,005)		(284)		15,155		(371)
Purchases	9,958		9,267		10,806		9,732
Settlements	(2,475)		(2,039)		(21,640)		(7,099)
Ending balance	$	7,501	$	8,040	$	7,501	$	8,040
* Cleco Power’s unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet. Cleco Cajun’s unrealized (losses) gains are reported through Purchased power on Cleco’s Condensed Consolidated Income Statement.

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Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Beginning balance	$	1,088	$	1,149	$	3,216	$	5,725
Unrealized (losses)gains*	(402)		1,298		(402)		1,298
Purchases	7,768		7,311		8,616		7,776
Settlements	(2,464)		(2,247)		(5,440)		(7,288)
Ending balance	$	5,990	$	7,511	$	5,990	$	7,511
* Unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheet.

The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions for Cleco and Cleco Power as of June 30, 2021, and December 31, 2020:

Cleco
	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW		HIGH
FTRs at June 30, 2021	$	8,662	$	1,161	RTO auction pricing	FTR price - per MWh	$	(5.73)	$	7.28
FTRs at Dec. 31, 2020	$	4,805	$	1,625	RTO auction pricing	FTR price - per MWh	$	(3.49)	$	4.36

Cleco Power
	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW		HIGH
FTRs at June 30, 2021	$	6,867	$	877	RTO auction pricing	FTR price - per MWh	$	(2.03)	$	7.28
FTRs at Dec. 31, 2020	$	4,337	$	1,121	RTO auction pricing	FTR price - per MWh	$	(3.34)	$	4.36

At June 30, 2021, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents and restricted cash equivalents. The following tables present the institutional money market funds in cash and cash equivalents and restricted cash and cash equivalents as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021, and December 31, 2020:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Cash and cash equivalents	$	73,412	$	80,712
Current restricted cash and cash equivalents	$	2,949	$	4,545
Non-current restricted cash and cash equivalents	$	744	$	744

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Cash and cash equivalents	$	16,112	$	20,812
Current restricted cash and cash equivalents	$	2,949	$	4,545

Institutional money market fund assets are discounted to the current period using a published U.S. Treasury interest rate as a proxy for a risk-free rate of return. If the money market funds failed to perform under the terms of the investments, Cleco and Cleco Power would be exposed to a loss of the invested amounts. Collateral on these types of investments is not required by either Cleco or Cleco Power. The Level 2 institutional money market funds asset consists of a single class. In order to capture interest income and minimize risk, cash is invested in money market funds that invest primarily in

short-term securities issued by the U.S. Treasury to maintain liquidity and achieve the goal of a net asset value of a dollar. The risks associated with this class are counterparty risk of the fund manager and risk of price volatility associated with the underlying securities of the fund.

Derivatives and other commodity contracts that do not qualify for derivative accounting treatment transacted directly with a counterparty and are not cleared on an exchange contain counterparty credit risk. Cleco may be required to provide credit support or pay liquidated damages with respect to any open trading contracts that Cleco has entered into or may enter into in the future. The amount of credit support that Cleco may be required to provide at any point in the future is dependent on the amount of the initial contract, changes in the market price, changes in open contracts, and changes in the amounts counterparties owe to Cleco. Changes in any of these factors could cause the amount of requested credit support to increase or decrease.

Cleco Power and Cleco Cajun’s FTRs are valued using MISO’s monthly auction prices. Forward seasonal periods are not included in every monthly auction; therefore, the average of the most recent seasonal auction prices is used for monthly valuation. FTRs are categorized as Level 3 fair value measurements because the only relevant value available comes from MISO auctions, which occur monthly in the Multi-Period Monthly Auction.

During the six months ended June 30, 2021, and the year ended December 31, 2020, Cleco did not experience any transfers between levels within the fair value hierarchy.

Commodity Contracts

The following tables present the fair values of derivative instruments and their respective line items as recorded on

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Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021, and December 31, 2020:

Cleco
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2021		AT DEC. 31, 2020
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	8,662	$	4,805
Current	Energy risk management liabilities	(1,161)		(1,625)
Other commodity derivatives
Current	Energy risk management assets	30,063		8,276
Non-current	Other deferred charges	25,771		323
Current	Energy risk management liabilities	—		(828)
Non-current	Other deferred credits	—		(784)
Commodity-related contracts, net		$	63,335	$	10,167

Cleco Power
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2021		AT DEC. 31, 2020
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	6,867	$	4,337
Current	Energy risk management liabilities	(877)		(1,121)
Commodity-related contracts, net		$	5,990	$	3,216

The following tables present the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2021, and 2020:

Cleco
	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	INCOME STATEMENT LINE ITEM	2021		2020		2021		2020
Commodity-related contracts
FTRs(1)	Electric operations	$	1,763	$	1,852	$	9,207	$	3,248
FTRs(1)	Purchased power	702		92		(7,858)		(289)
Other commodity derivatives	Fuel used for electric generation	(51,683)		9,316		(57,897)		2,208
Total		$	(49,218)	$	11,260	$	(56,548)	$	5,167

(1) For the three and six months ended June 30, 2021, unrealized losses associated with FTRs for Cleco Power of $0.4 million were reported through Accumulated deferred fuel on the balance sheet. For the three and six months ended June 30, 2020, unrealized losses associated with FTRs for Cleco Power of $1.3 million were reported through Accumulated deferred fuel on the balance sheet.

Cleco Power
	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	INCOME STATEMENT LINE ITEM	2021		2020		2021		2020
Commodity-related contracts
FTRs(1)	Electric operations	$	1,763	$	1,852	$	9,208	$	3,249
FTRs(1)	Purchased power	(1,233)		(1,319)		(8,414)		(2,070)
Total		$	530	$	533	$	794	$	1,179

(1) For the three and six months ended June 30, 2021, unrealized losses associated with FTRs of $0.4 million were reported through Accumulated deferred fuel on the balance sheet. For the three and six months ended June 30, 2020, unrealized losses associated with FTRs of $1.3 million were reported through Accumulated deferred fuel on the balance sheet.

The total volume of FTRs that Cleco Power had outstanding at June 30, 2021, and December 31, 2020, was 19.8 million MWh and 9.5 million MWh, respectively. The total volume of FTRs that Cleco had outstanding at June 30, 2021, and December 31, 2020, was 30.9 million MWh and 15.3 million MWh, respectively. The total volume of other commodity derivatives Cleco had outstanding at June 30, 2021, and December 31, 2020, was 127.9 million MMBtus and 73.0 million MMBtus, respectively.

Note 7 — Debt

On May 21, 2021, Cleco Holdings entered into a $175.0 million revolving credit agreement and a $266.0 million term loan agreement. These agreements replaced Cleco Holdings’ existing revolving credit agreement and term loan agreement. The revolving credit agreement matures on May 21, 2026. Under this agreement, Cleco Holdings is required to maintain total indebtedness less than or equal to 65% of total

capitalization. The borrowing costs under this agreement are currently equal to LIBOR plus 1.625% or ABR plus 0.625%, plus commitment fees of 0.275%. If Cleco Holdings’ credit ratings were to be downgraded one level by the credit rating agencies, Cleco Holdings may be required to pay higher commitment fees and additional interest of 0.175%. At June 30, 2021, Cleco Holdings had no borrowings outstanding under its revolving credit agreement. Cleco Holdings’ term loan agreement matures on May 21, 2024 and has an interest rate of LIBOR plus 1.625% or ABR plus 0.625%.

In addition, on May 21, 2021, Cleco Power entered into a $300.0 million revolving credit agreement and a $125.0 million term loan agreement. These agreements replaced Cleco Power’s existing revolving credit agreement and term loan agreement. The revolving credit agreement matures on May 21, 2026. Under this agreement, Cleco Power is required to maintain total indebtedness less than or equal to 65% of total capitalization. The borrowing costs under this agreement are currently equal to LIBOR plus 1.25% or ABR plus 0.25%, plus

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commitment fees of 0.15%. If Cleco Power’s credit ratings were to be downgraded one level by the credit rating agencies, Cleco Power may be required to pay higher commitment fees and additional interest of 0.15%. At June 30, 2021, Cleco Power had $160.0 million of borrowings outstanding under the revolving credit agreement. Cleco Power’s term loan agreement matures on May 21, 2024 and has an interest rate of LIBOR plus 1.25% or ABR plus 0.25%.

Note 8 — Pension Plan and Employee Benefits

Pension Plan and Other Benefits Plan

Employees hired before August 1, 2007, are covered by a non-contributory, defined benefit pension plan. Based on the funding assumptions at December 31, 2020, and the funding relief provided by the American Rescue Plan Act, which was signed by the President on March 11, 2021, management

estimates that no pension contributions will be required through 2025. As of June 30, 2021, Cleco expects to make $67.0 million in discretionary contributions to the pension plan in 2021, which would offset future required contributions.

Cleco Power is the plan sponsor and Support Group is the plan administrator. Benefits under the plan reflect an employee’s years of service, age at retirement, and accrued benefit at retirement.

Cleco’s retirees may be eligible to receive Other Benefits. Dependents of Cleco’s retirees may also be eligible to receive Other Benefits with the exception of life insurance benefits.

The non-service components of net periodic pension and Other Benefits cost are included in Other income (expense), net within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. The components of net periodic pension and Other Benefits cost for the three and six months ended June 30, 2021, and 2020 were as follows:

	PENSION BENEFITS				OTHER BENEFITS
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	2,730	$	2,582	$	595	$	508
Interest cost	4,719		5,278		323		410
Expected return on plan assets	(5,698)		(6,242)		—		—
Amortizations
Prior period service credit	—		(15)		—		—
Net loss	5,607		4,477		384		340
Net periodic benefit cost	$	7,358	$	6,080	$	1,302	$	1,258

	PENSION BENEFITS				OTHER BENEFITS
	FOR THE SIX MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	5,258	$	4,910	$	1,190	$	1,015
Interest cost	9,334		10,408		645		820
Expected return on plan assets	(11,400)		(12,487)		—		—
Amortizations
Prior period service credit	—		(30)		—		—
Net loss	10,369		8,149		770		680
Net periodic benefit cost	$	13,561	$	10,950	$	2,605	$	2,515

Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2021, was $0.9 million and $1.8 million, respectively. The expense of the pension plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2020, was $1.3 million and $1.7 million, respectively.

Cleco Holdings is the plan sponsor for the other benefit plans. There are no assets set aside in a trust, and the liabilities are reported on the individual subsidiaries’ financial statements. The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2021, was $1.2 million and $2.4 million, respectively. The expense related to other benefits reflected in Cleco Power’s Condensed

Consolidated Statements of Income for the three and six months ended June 30, 2020, was $1.2 million and $2.5 million, respectively. The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at June 30, 2021, and December 31, 2020, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	4,463	$	4,463
Non-current	$	51,522	$	51,868

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	3,865	$	3,865
Non-current	$	40,449	$	40,734

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SERP

Certain Cleco officers are covered by SERP. Cleco does not fund the SERP liability, but instead pays for current benefits out of general funds available. Cleco Power has formed a rabbi trust. The life insurance policies issued on SERP participants designate the rabbi trust as the beneficiary. Market conditions could have a significant impact on the cash surrender value of the life insurance policies. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ death benefits, as well as future SERP payments. However, because SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. All SERP benefits are paid out of general cash available of the respective companies that employed the officer. Cleco Power is the plan sponsor and Support Group is the plan administrator.

The non-service components of net periodic benefit cost related to SERP are included in Other income (expense), net within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. The components of the net periodic benefit cost related to SERP for the three and six months ended June 30, 2021, and 2020 were as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	61	$	105	$	116	$	200
Interest cost	644		734		1,269		1,466
Amortizations
Prior period service credit	(55)		(67)		(107)		(107)
Net (gain) loss	(401)		835		613		1,592
Net periodic benefit cost	$	249	$	1,607	$	1,891	$	3,151

The expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2021, was less than $0.1 million and $0.3 million, respectively. The expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2020, was $0.2 million and $0.5 million, respectively.

Liabilities relating to SERP are reported on the individual subsidiaries’ financial statements. The current and non-current portions of the SERP liability for Cleco and Cleco Power at June 30, 2021, and December 31, 2020, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	4,703	$	4,703
Non-current	$	91,355	$	92,522

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	711	$	711
Non-current	$	19,364	$	19,828

401(k) Plan

Cleco’s 401(k) Plan is intended to provide active, eligible employees with voluntary, long-term savings and investment opportunities. The 401(k) Plan is a defined contribution plan and is subject to the applicable provisions of the Employee

Retirement Income Security Act of 1974. In accordance with the 401(k) Plan, employer contributions are made in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Participation in the Plan is voluntary, and active Cleco employees are eligible to participate. Cleco’s 401(k) Plan expense for the three and six months ended June 30, 2021, and 2020 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
401(k) Plan expense	$	2,120	$	1,898	$	4,880	$	5,154

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2021, and 2020 was as follows:

	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
401(k) Plan expense	$	946	$	832	$	2,326	$	2,495

Note 9 — Income Taxes

Effective Tax Rates

The following tables summarize the effective income tax rates for Cleco and Cleco Power for the three and six months ended June 30, 2021, and 2020:

Cleco
	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30
	2021		2020		2021		2020
Effective tax rate	11.1	%	23.9	%	0.4	%	23.4	%

Cleco Power
	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2021		2020		2021		2020
Effective tax rate	24.6	%	24.9	%	(1.7)	%	24.1	%

For the three and six months ended June 30, 2021, the effective income tax rates for both Cleco and Cleco Power were different than the federal statutory rate primarily due to the amortization of excess ADIT, adjustment to record tax expense at the projected annual effective tax rate, and state tax expense.

For the three and six months ended June 30, 2020, the effective income tax rates for both Cleco and Cleco Power were different than the federal statutory rate primarily due to the adjustment to record tax expense at the projected annual effective tax rate; the flow through of tax benefits, including AFUDC equity; and state tax expense.

Uncertain Tax Positions

Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. At June 30, 2021, and December 31, 2020, Cleco and Cleco Power had no liability for uncertain tax positions or interest payable related to uncertain tax positions. Cleco estimates that it is

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reasonably possible that the balance of unrecognized tax benefits as of June 30, 2021, for Cleco and Cleco Power would be unchanged in the next 12 months. The settlement of open tax years could involve the payment of additional taxes, and/or the recognition of tax benefits, which may have an effect on Cleco’s effective tax rate.

Income Tax Audits

Cleco participates in the IRS’s Compliance Assurance Process in which tax positions are examined and agreed upon prior to filing the federal tax return. While the statute of limitations remains open for tax years 2017, 2018, and 2019, the IRS has completed its review of years 2017 through 2019, and these tax returns were filed consistent with the IRS’s review. The IRS has placed Cleco in the Bridge phase of the Compliance Assurance Process for the 2020 tax year. In this phase, the IRS will not accept any disclosures, conduct any reviews, or provide any assurances.

The state income tax years 2017, 2018, and 2019 remain open to examination by the Louisiana Department of Revenue.

Cleco classifies income tax penalties as a component of other expense. For the three and six months ended June 30, 2021, and 2020, no penalties were recognized.

CARES Act

In March 2020, the CARES Act was signed into law. The CARES Act includes tax relief provisions such as an alternative minimum tax credit refund, a five-year net operating loss carryback from years 2018 through 2020, and deferred payments of employer payroll taxes.

Cleco deferred $6.0 million in employer payroll tax payments for the period March 27, 2020, through December 31, 2020. Cleco will pay $3.0 million of the obligation by December 31, 2021, and the remaining $3.0 million by December 31, 2022.

Cleco Power deferred $3.6 million in employer payroll tax payments for the period March 27, 2020, through December 31, 2020. Cleco Power will pay $1.8 million of the obligation by December 31, 2021, and the remaining $1.8 million by December 31, 2022.

The CARES Act also includes modifications on the limitations of business interest for the 2019 and 2020 tax years. The modifications increase the allowable business interest deduction from 30% to 50% of adjusted taxable income. Cleco does not anticipate having any disallowed interest for the 2020 tax year.

Consolidated Appropriations Act of 2021

In December 2020, the Consolidated Appropriations Act of 2021 (CAA) was signed into law. The CAA includes COVID-19 tax relief and tax extender provisions including extensions of time to begin construction on and placed in-service assets generating production tax credits and income tax credits, 100% deductibility of business meals in 2021 and 2022, and an extension of the work opportunity tax credit. The income tax

credit percentage has been increased for projects starting construction through 2023 and placed in service by the end of 2025. Management does not expect the CAA to have a material impact on the Registrants.

American Jobs Act of 2021

On March 31, 2021, the President announced the American Jobs Act. This proposal includes a number of incentives to encourage construction of certain transmission and energy storage property. The proposed act also proposes to raise the federal statutory corporate income tax rate from 21% to 28% and to introduce a minimum tax based on book income. Currently, management is unable to predict the impact of the proposed act on the Registrants.

Note 10 — Disclosures about Segments

Cleco’s reportable segments are based on its method of internal reporting, which disaggregates business units by its first-tier subsidiary. Cleco’s reportable segments are Cleco Power and Cleco Cajun.

Each reportable segment engages in business activities from which it earns revenue and incurs expenses. Segment managers report periodically to Cleco’s CEO, who is Cleco’s chief operating decision maker, with discrete financial information and, at least quarterly, present discrete financial information to Cleco and, in the case of Cleco Power, Cleco Power’s Boards of Managers. The reportable segment prepares budgets that are presented to and approved by Cleco and, in the case of Cleco Power, Cleco Power’s Boards of Managers. The column shown as Other in the following tables includes the holding company, a shared services subsidiary, and an investment subsidiary. There were no changes to Cleco’s existing reportable segments.

The financial results in the following tables are presented on an accrual basis. EBITDA is a key non-GAAP financial measure used by the CEO to assess the operating performance of Cleco’s segments. Management evaluates the performance of Cleco’s segments and allocates resources to them based on segment profit and the requirements to implement strategic initiatives and projects to meet current business objectives. EBITDA is defined as net income adjusted for interest, income taxes, depreciation, and amortization. Depreciation and amortization in the following tables includes amortization of intangible assets and liabilities recorded for the fair value adjustment of wholesale power supply agreements as a result of the 2016 Merger and the Cleco Cajun Transaction, as well as amortization of deferred lease revenue resulting from the Cleco Cajun Transaction. Material intercompany transactions occur on a regular basis. These intercompany transactions relate primarily to joint and common administrative support services as well as transmission services provided by Cleco Power to Cleco Cajun.

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Segment Information for the Three Months Ended June 30,
2021 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	262,948	$	91,407		$	354,355
Other operations	16,269		30,655			46,924
Affiliate revenue	1,224		—			1,224
Electric customer credits	(18,762)		244			(18,518)
Operating revenue, net	$	261,679	$	122,306		$	383,985
Net income	$	27,421	$	52,494		$	79,915
Add: Depreciation and amortization	40,933		12,339		(1)	53,272
Less: Interest income	825		3			828
Add: Interest charges	18,237		(180)			18,057
Add: Federal and state income tax expense	8,956		18,063			27,019
EBITDA	$	94,722	$	82,713		$	177,435
(1) Includes $3.3 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(2.3) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2021 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	354,355	$	(2,420)		$	1	$	351,936
Other operations	46,924		1			(1,595)		45,330
Affiliate revenue	1,224		26,120			(27,344)		—
Electric customer credits	(18,518)		—			1		(18,517)
Operating revenue, net	$	383,985	$	23,701		$	(28,937)	$	378,749
Depreciation and amortization	$	53,272	$	4,427	(1)	$	—	$	57,699
Interest income	$	828	$	14		$	(13)	$	829
Interest charges	$	18,057	$	15,248		$	(14)	$	33,291
Federal and state income tax (benefit)	$	27,019	$	(17,182)		$	—	$	9,837
Net income (loss)	$	79,915	$	(1,093)		$	—	$	78,822
(1) Includes $2.4 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

2020 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	239,643	$	84,733		$	324,376
Other operations	15,904		30,636			46,540
Affiliate revenue	1,240		43			1,283
Electric customer credits	(9,100)		—			(9,100)
Operating revenue, net	$	247,687	$	115,412		$	363,099
Net income	$	28,233	$	26,762		$	54,995
Add: Depreciation and amortization	41,596		11,143		(1)	52,739
Less: Interest income	755		103			858
Add: Interest charges	18,603		120			18,723
Add: Federal and state income tax expense	9,356		8,601			17,957
EBITDA	$	97,033	$	46,523		$	143,556
(1) Includes $3.1 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(2.3) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

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2020 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	324,376	$	(2,420)		$	—	$	321,956
Other operations	46,540		1			(1,639)		44,902
Affiliate revenue	1,283		29,138			(30,421)		—
Electric customer credits	(9,100)		—			—		(9,100)
Operating revenue, net	$	363,099	$	26,719		$	(32,060)	$	357,758
Depreciation and amortization	$	52,739	$	4,565	(1)	$	—	$	57,304
Interest income	$	858	$	55		$	(15)	$	898
Interest charges	$	18,723	$	16,007		$	(15)	$	34,715
Federal and state income tax expense (benefit)	$	17,957	$	(4,364)		$	—	$	13,593
Net income (loss)	$	54,995	$	(11,826)		$	(1)	$	43,168
(1) Includes $2.4 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

Segment Information for the Six Months Ended June 30,
2021 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	530,107	$	192,914		$	723,021
Other operations	34,895		63,694			98,589
Affiliate revenue	2,879		—			2,879
Electric customer credits	(39,738)		244			(39,494)
Operating revenue, net	$	528,143	$	256,852		$	784,995
Net income	$	45,846	$	66,975		$	112,821
Add: Depreciation and amortization	83,009		23,991		(2)	107,000
Less: Interest income	1,468		6			1,474
Add: Interest charges	36,883		(332)			36,551
Add: Federal and state income tax (benefit) expense	(767)		22,673			21,906
EBITDA	$	163,503	$	113,301		$	276,804
Additions to property, plant, and equipment	$	134,185	$	4,882		$	139,067
Equity investment in investees (1)	$	5,572	$	—		$	5,572
Goodwill (1)	$	1,490,797	$	—		$	1,490,797
Total segment assets (1)	$	6,438,218	$	1,078,534		$	7,516,752
(1) Balances as of June 30, 2021. (2) Includes $6.4 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(4.6) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2021 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	723,021	$	(4,840)		$	—	$	718,181
Other operations	98,589		2			(3,535)		95,056
Affiliate revenue	2,879		53,276			(56,155)		—
Electric customer credits	(39,494)		—			—		(39,494)
Operating revenue, net	$	784,995	$	48,438		$	(59,690)	$	773,743
Depreciation and amortization	$	107,000	$	8,862	(2)	$	—	$	115,862
Interest income	$	1,474	$	57		$	(56)	$	1,475
Interest charges	$	36,551	$	30,687		$	(55)	$	67,183
Federal and state income tax expense (benefit)	$	21,906	$	(21,490)		$	—	$	416
Net income (loss)	$	112,821	$	(13,672)		$	—	$	99,149
Additions to property, plant, and equipment	$	139,067	$	1,440		$	—	$	140,507
Equity investment in investees (1)	$	5,572	$	—		$	—	$	5,572
Goodwill (1)	$	1,490,797	$	—		$	—	$	1,490,797
Total segment assets (1)	$	7,516,752	$	569,126		$	(144,409)	$	7,941,469
(1) Balances as of June 30, 2021. (2) Includes $4.8 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

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2020 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	464,073	$	173,880		$	637,953
Other operations	31,668		61,597			93,265
Affiliate revenue	2,346		204			2,550
Electric customer credits	(17,440)		(153)			(17,593)
Operating revenue, net	$	480,647	$	235,528		$	716,175
Net income	$	40,064	$	46,298		$	86,362
Add: Depreciation and amortization	85,273		22,041		(2)	107,314
Less: Interest income	1,709		258			1,967
Add: Interest charges	37,184		131			37,315
Add: Federal and state income tax expense	12,694		15,022			27,716
EBITDA	$	173,506	$	83,234		$	256,740
Additions to property, plant, and equipment	$	132,578	$	5,417		$	137,995
Equity investment in investees (1)	$	9,072	$	—		$	9,072
Goodwill (1)	$	1,490,797	$	—		$	1,490,797
Total segment assets (1)	$	6,256,944	$	1,029,812		$	7,286,756
(1) Balances as of December 31, 2020. (2) Includes $6.2 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(4.6) million deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2020 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	637,953	$	(4,840)		$	—	$	633,113
Other operations	93,265		1			(3,456)		89,810
Affiliate revenue	2,550		58,415			(60,965)		—
Electric customer credits	(17,593)		—			—		(17,593)
Operating revenue, net	$	716,175	$	53,576		$	(64,421)	$	705,330
Depreciation and amortization	$	107,314	$	9,079	(2)	$	—	$	116,393
Interest income	$	1,967	$	155		$	(68)	$	2,054
Interest charges	$	37,315	$	32,617		$	(69)	$	69,863
Federal and state income tax expense (benefit)	$	27,716	$	(12,561)		$	—	$	15,155
Net income (loss)	$	86,362	$	(36,865)		$	(1)	$	49,496
Additions to property, plant, and equipment	$	137,995	$	1,344		$	—	$	139,339
Equity investment in investees (1)	$	9,072	$	—		$	—	$	9,072
Goodwill (1)	$	1,490,797	$	—		$	—	$	1,490,797
Total segment assets (1)	$	7,286,756	$	595,217		$	(156,404)	$	7,725,569
(1) Balances as of December 31, 2020. (2) Includes $4.8 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Net income	$	78,822	$	43,168	$	99,149	$	49,496
Add: Depreciation and amortization	57,699		57,304		115,862		116,393
Less: Interest income	829		898		1,475		2,054
Add: Interest charges	33,291		34,715		67,183		69,863
Add: Federal and state income tax expense	9,837		13,593		416		15,155
Add: Other corporate costs and noncash items (1)	(1,385)		(4,326)		(4,331)		7,887
Total segment EBITDA	$	177,435	$	143,556	$	276,804	$	256,740
(1) Adjustments made for Other and Elimination totals not allocated to total segment EBITDA.

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Note 11 — Regulation and Rates

Provision for rate refund on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets consisted primarily of the following:

(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
FRP	$	2,392	$	1,786
TCJA	$	2,057	$	2,057
Cleco Katrina/Rita storm recovery charges	$	1,610	$	1,617
Site-specific industrial customer	$	990	$	710
Transmission ROE	$	250	$	595
FERC audit	$	—	$	1,912

FRP

Prior to July 1, 2021, Cleco Power’s annual retail earnings were subject to an FRP established by the LPSC in June 2014. The 2014 FRP allowed Cleco Power to earn a target ROE of 10.0%, while providing the opportunity to earn up to 10.9%. Additionally, 60.0% of retail earnings between 10.9% and 11.75%, and all retail earnings over 11.75%, were required to be refunded to customers. In June 2019, Cleco Power filed an application with the LPSC for a new FRP. The FRP rates previously established remained in effect due to delays in the base rate case. On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan. Effective July 1, 2021, under the terms of the new FRP, Cleco Power is allowed to earn a target ROE of 9.5%, while providing the opportunity to earn up to 10.0%. Additionally, 60.0% of retail earnings between 10.0% and 10.5%, and all retail earnings over 10.5%, are required to be refunded to customers. The amount of credits due to customers, if any, is determined by Cleco Power and the LPSC annually. Cleco Power’s next base rate case is required to be filed with the LPSC on or before March 31, 2023.

Cleco Power filed its monitoring report for the 12 months ended June 30, 2019, on October 31, 2019, indicating that no refund was due. On June 30, 2021, the LPSC Staff filed their report indicating agreement with Cleco Power’s refund calculation for the 12 months ending June 30, 2019. Cleco Power anticipates approval of the report from the LPSC in the third quarter of 2021. Monitoring reports for the 12 months ended June 30, 2020, and 2021 were not required due to the expiration of the 2014 FRP. The next monitoring report will be filed on or before October 31, 2022, for the 12 months ending June 30, 2022.

Cleco Power continued to accrue the annual cost of service savings resulting from the 2016 Merger Commitments through June 30, 2021. Beginning July 1, 2021, the annual cost of service savings are included in Cleco Power’s new retail rate plan. At June 30, 2021, Cleco Power had $2.4 million accrued for the period July 1, 2019, through June 30, 2021. Cleco Power expects to refund its customers $1.2 million in September 2021 and September 2022.

TCJA

The provisions of the TCJA reduced the top federal statutory corporate income tax rate from 35% to 21%. As a result of the tax rate reduction, on January 1, 2018, Cleco Power began accruing an estimated reserve for the reduction in the federal statutory corporate income tax rate. In February 2018, the LPSC directed utilities, including Cleco Power, to provide considerations of the appropriate manner to flow through to ratepayers the benefits of the reduction in corporate income

taxes as a result of the TCJA. In July 2019, the LPSC approved Cleco Power’s rate refund of $79.2 million, plus interest, for the reduction in the statutory federal tax rate for the period from January 2018 to June 2020. The refund was credited to customers over 12 months beginning August 1, 2019.

In July 2019, the LPSC approved Cleco Power’s motion to address the rate redesign and the regulatory liability for excess ADIT, resulting from the enactment of the TCJA, in Cleco Power’s current base rate case.

As a result of the delay in the rate case, on July 15, 2020, the LPSC approved Cleco Power’s application to extend the TCJA bill credits at the same rate as determined in the initial TCJA refund of approximately $7.0 million per month. The extension was for the period of August 2020 through November 2020. On November 13, 2020, Cleco Power again received approval for its application to extend the TCJA bill credits from November 30, 2020, until such a time that the rate case was completed. The $7.0 million monthly refund consisted of approximately $4.4 million, which was to be funded by the unprotected excess ADIT, and approximately $2.6 million, which is the change in the federal statutory corporate income tax rate from 35% to 21%. At June 30, 2021, Cleco Power had $2.1 million accrued for the estimated federal tax-related benefits from the TCJA.

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan which includes the settlement of the TCJA protected and unprotected excess ADIT. Effective July 1, 2021, all retail customers will continue receiving bill credits resulting from the TCJA. The target retail portion of the unprotected excess ADIT is approximately $2.5 million monthly and will be credited over a period of three years concluding on June 30, 2024. The retail portion of the protected excess ADIT will be credited until the full amount of the protected excess ADIT has been returned to Cleco Power’s customers through bill credits. At June 30, 2021, Cleco Power had $324.6 million accrued for the excess ADIT, of which $39.5 million is reflected in current regulatory liabilities.

Cleco Katrina/Rita Storm Recovery Charges

Prior to the repayment of the storm recovery bonds in March 2020, Cleco Katrina/Rita had the right to bill and collect storm restoration costs from Cleco Power’s customers to pay administrative fees, interest, and principal on the Cleco Katrina/Rita storm recovery bonds. Amounts remaining after the final principal and interest payments on the storm recovery bonds and payments for final administrative and winding up activities are subject to refund. At June 30, 2021, Cleco Power had $1.6 million accrued for Cleco Katrina/Rita storm recovery charges that are subject to refund. For more information on Cleco Katrina/Rita’s restricted cash, see Note 1 — “Summary of Significant Accounting Policies — Restricted Cash and Cash Equivalents.”

Transmission ROE

Two complaints were filed with FERC seeking to reduce the ROE component of the transmission rates that MISO transmission owners, including Cleco Power, may collect under the MISO tariff. As of June 30, 2021, Cleco Power had $0.3 million accrued for the change in ROE. For more information on the ROE complaints, see Note 13 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — Transmission ROE.”

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FERC Audit

As of June 30, 2021, the estimated refund was fully refunded to Cleco Power’s wholesale transmission customers as a combination of refund payments and a reduction in Attachment O of the MISO tariff and grandfathered agreement rates over the preceding 12 months. For more information about the FERC audit, see Note 13 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — FERC Audit.”

SSR

In September 2016, Cleco Power filed an Attachment Y with MISO requesting retirement of Teche Unit 3 effective April 1, 2017. MISO conducted a study which determined the proposed retirement of Teche Unit 3 would result in violations of specific applicable reliability standards for which no mitigation is available. As a result, MISO designated Teche Unit 3 as an SSR unit until such time that an appropriate alternative solution could be implemented to mitigate reliability issues. One mitigating factor identified was Cleco Power’s Terrebonne to Bayou Vista Transmission project, which was completed in April 2019. Cleco Power received a termination notice, effective April 30, 2019, and filed paperwork to withdraw the filed Attachment Y. While operating as an SSR unit, Cleco Power received monthly payments that included recovery of expenses, including capital expenditures, related to the operations of Teche Unit 3. Additionally, MISO allocated SSR costs to the load serving entities that required the operation of the SSR unit, including Cleco Power. These payments and cost allocations were finalized as part of a MISO SSR settlement approved in December 2018. Cleco Power operated Teche Unit 3 as an SSR unit from April 2017 until April 2019.

Cleco Power expects Teche Unit 3 to continue to be available to run and to continue to offer the unit into MISO through 2024, barring a significant unit failure. At June 30, 2021, Cleco Power had $4.3 million accrued for the net capital refund for capital expenditures paid for by third parties while operating under the SSR agreement. The capital refund is expected to be paid in early 2022.

Note 12 — Variable Interest Entities

Cleco and Cleco Power apply the equity method of accounting to report the investment in Oxbow in the consolidated financial statements. Under the equity method, the assets and liabilities of this entity are reported as Equity investment in investee on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of this entity are netted and reported as equity income or loss from investees on Cleco and Cleco Power’s Condensed Consolidated Statements of Income.

Oxbow is owned 50% by Cleco Power and 50% by SWEPCO. Cleco Power is not the primary beneficiary because it shares the power to control Oxbow’s significant activities with SWEPCO. Cleco Power’s current assessment of its maximum exposure to loss related to Oxbow at June 30, 2021, consisted of its equity investment of $5.6 million. During the six months ended June 30, 2021, Cleco Power had a return of equity investment from Oxbow of $3.5 million.

The following table presents the components of Cleco Power’s equity investment in Oxbow:

INCEPTION TO DATE (THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Purchase price	$	12,873	$	12,873
Cash contributions	6,399		6,399
Distributions	(13,700)		(10,200)
Total equity investment in investee	$	5,572	$	9,072

The following table compares the carrying amount of Oxbow’s assets and liabilities with Cleco Power’s maximum exposure to loss related to its investment in Oxbow:

(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Oxbow’s net assets/liabilities	$	11,145	$	18,145
Cleco Power’s 50% equity	$	5,572	$	9,072
Cleco Power’s maximum exposure to loss	$	5,572	$	9,072

The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Operating revenue	$	1,627	$	29,110	$	3,626	$	30,991
Operating expenses	1,627		29,110		3,626		30,991
Income before taxes	$	—	$	—	$	—	$	—

Prior to June 30, 2020, DHLC mined lignite reserves at Oxbow through the Amended Lignite Mining Agreement. The lignite reserves were intended to be used to provide fuel to the Dolet Hills Power Station. Under the Amended Lignite Mining Agreement, DHLC bills Cleco Power its proportionate share of incurred lignite extraction and associated mining-related costs. Oxbow bills Cleco Power its proportionate share of incurred costs related to mineral rights and land leases. For more information on DHLC and the Oxbow mine, see Note 13 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Risks and Uncertainties.”

Oxbow has no third-party agreements, guarantees, or other third-party commitments that contain obligations affecting Cleco Power’s investment in Oxbow.

Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees

Litigation

2016 Merger

In connection with the 2016 Merger, four actions were filed in the Ninth Judicial District Court for Rapides Parish, Louisiana and three actions were filed in the Civil District Court for Orleans Parish, Louisiana. The petitions in each action generally alleged, among other things, that the members of Cleco Corporation’s Board of Directors breached their fiduciary duties by, among other things, conducting an allegedly inadequate sale process, agreeing to the 2016 Merger at a price that allegedly undervalued Cleco, and failing to disclose material information about the 2016 Merger. The petitions also alleged that Como 1, Cleco Corporation, Merger Sub, and, in some cases, certain of the investors in Como 1 either aided and abetted or entered into a civil conspiracy to

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advance those supposed breaches of duty. The petitions sought various remedies, including monetary damages, which includes attorneys’ fees and expenses.

The four actions filed in the Ninth Judicial District Court for Rapides Parish are captioned as follows:

•Braunstein v. Cleco Corporation, No. 251,383B (filed October 27, 2014),

•Moore v. Macquarie Infrastructure and Real Assets, No. 251,417C (filed October 30, 2014),

•Trahan v. Williamson, No. 251,456C (filed November 5, 2014), and

•L’Herisson v. Macquarie Infrastructure and Real Assets, No. 251,515F (filed November 14, 2014).

In November 2014, the plaintiff in the Braunstein action moved for a dismissal of the action without prejudice, and that motion was granted in November 2014. In December 2014, the Court consolidated the remaining three actions and appointed interim co-lead counsel, and dismissed the investors in Cleco Partners as defendants, per agreement of the parties. Also, in December 2014, the plaintiffs in the consolidated action filed a Consolidated Amended Verified Derivative and Class Action Petition for Damages and Preliminary and Permanent Injunction.

The three actions filed in the Civil District Court for Orleans Parish were captioned as follows:

•Butler v. Cleco Corporation, No. 2014-10776 (filed November 7, 2014),

•Creative Life Services, Inc. v. Cleco Corporation, No. 2014-11098 (filed November 19, 2014), and

•Cashen v. Cleco Corporation, No. 2014-11236 (filed November 21, 2014). 

In December 2014, the directors and Cleco filed declinatory exceptions in each action on the basis that each action was improperly brought in Orleans Parish and should either be transferred to the Ninth Judicial District Court for Rapides Parish or dismissed. Also, in December 2014, the plaintiffs in each action jointly filed a motion to consolidate the three actions pending in Orleans Parish and to appoint interim co-lead plaintiffs and co-lead counsel. In January 2015, the Court in the Creative Life Services case sustained the defendants’ declinatory exceptions and dismissed the case so that it could be transferred to the Ninth Judicial District Court for Rapides Parish. In February 2015, the plaintiffs in Butler and Cashen also consented to the dismissal of their cases from Orleans Parish so they could be transferred to the Ninth Judicial District Court for Rapides Parish. By operation of the December 2014 order of the Ninth Judicial District Court for Rapides Parish, the Butler, Cashen, and Creative Life Services actions were consolidated into the actions pending in Rapides Parish.

In February 2015, the Ninth Judicial District Court for Rapides Parish held a hearing on a motion for preliminary injunction filed by plaintiffs in the consolidated action seeking to enjoin the shareholder vote for approval of the Merger Agreement. The District Court heard and denied the plaintiffs’ motion. In June 2015, the plaintiffs filed their Second Consolidated Amended Verified Derivative and Class Action Petition. Cleco filed exceptions seeking dismissal of the second amended petition in July 2015. The LPSC voted to

approve the 2016 Merger before the Court could consider the plaintiffs’ peremptory exceptions.

In March 2016 and May 2016, the plaintiffs filed their Third Consolidated Amended Verified Derivative Petition for Damages and Preliminary and Permanent Injunction and their Fourth Verified Consolidated Amended Class Action Petition, respectively. The fourth amended petition, which remains the operative petition and was filed after the 2016 Merger closed, eliminated the request for preliminary and permanent injunction and also named an additional executive officer as a defendant. The defendants filed exceptions seeking dismissal of the fourth amended Petition. In September 2016, the District Court granted the exceptions of no cause of action and no right of action and dismissed all claims asserted by the former shareholders. The plaintiffs appealed the District Court’s ruling to the Louisiana Third Circuit Court of Appeal. In December 2017, the Third Circuit Court of Appeal issued an order reversing and remanding the case to the District Court for further proceedings. In January 2018, Cleco filed a writ with the Louisiana Supreme Court seeking review of the Third Circuit Court of Appeal’s decision. The writ was denied in March 2018 and the parties are engaged in discovery in the District Court. In November 2018, Cleco filed renewed exceptions of no cause of action and res judicata, seeking to dismiss all claims. On December 21, 2018, the court dismissed Cleco Partners and Cleco Holdings as defendants per the agreement of the parties, leaving as the only remaining defendants certain former executive officers and independent directors. The District Court denied the defendants’ exceptions on January 14, 2019. A hearing on the plaintiffs’ motion for certification of a class was scheduled for August 26, 2019; however, prior to the hearing, the parties reached an agreement to certify a limited class. On September 7, 2019, the District Court certified a class limited to shareholders who voted against, abstained from voting, or did not vote on the 2016 Merger. Cleco believes that the allegations of the petitions in each action are without merit and that it has substantial meritorious defenses to the claims set forth in each of the petitions.

Gulf Coast Spinning

In September 2015, a potential customer sued Cleco for failure to fully perform an alleged verbal agreement to lend or otherwise fund its startup costs to the extent of $6.5 million. Gulf Coast Spinning Company, LLC (Gulf Coast), the primary plaintiff, alleges that Cleco promised to assist it in raising approximately $60.0 million, which Gulf Coast needed to construct a cotton spinning facility near Bunkie, Louisiana. According to the petition filed by Gulf Coast in the 12th Judicial District Court for Avoyelles Parish, Louisiana (the “District Court”), Cleco made such promises of funding assistance in order to cultivate a new industrial electric customer which would increase its revenues under a power supply agreement that it executed with Gulf Coast. Gulf Coast seeks unspecified damages arising from its inability to raise sufficient funds to complete the project, including lost profits.

Cleco filed an Exception of No Cause of Action arguing that the case should be dismissed. The District Court denied Cleco’s exception in December 2015, after considering briefs and arguments. In January 2016, Cleco appealed the District Court’s denial of its exception by filing with the Third Circuit Court of Appeal. In June 2016, the Third Circuit Court of Appeal denied the request to have the case dismissed. In July 2016, Cleco filed a writ to the Louisiana Supreme Court

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seeking a review of the District Court’s denial of Cleco’s exception. In November 2016, the Louisiana Supreme Court denied Cleco’s writ application.

In February 2016, the parties agreed to a stay of all proceedings pending discussions concerning settlement. In May 2016, the District Court lifted the stay at the request of Gulf Coast. The parties are currently participating in discovery. Cleco believes the allegations of the petition are contradicted by the written documents executed by Gulf Coast, are otherwise without merit, and that it has substantial meritorious defenses to the claims alleged by Gulf Coast.

Dispute with Saulsbury Industries

In October 2018, Cleco Power sued Saulsbury Industries, Inc., the former general contractor for the St. Mary Clean Energy Center project, seeking damages for Saulsbury Industries, Inc.’s failure to complete the St. Mary Clean Energy Center project on time and for costs incurred by Cleco Power in hiring a replacement general contractor. The action was filed in the Ninth Judicial District Court for Rapides Parish, No. 263339. Saulsbury Industries, Inc. removed the case to the U.S. District Court for the Western District of Louisiana, on March 1, 2019. On September 14, 2020, Cabot Industries was allowed to join the case pending in the Ninth Judicial District Court for Rapides Parish.

In January 2019, Cleco Power was served with a summons in Saulsbury Industries, Inc. v. Cabot Corporation and Cleco Power LLC, in the U.S. District Court for the Western District of Louisiana. Saulsbury Industries, Inc. alleged that Cleco Power and Cabot Corporation caused delays in the St. Mary Clean Energy Center project, resulting in alleged impacts to Saulsbury Industries, Inc.’s direct and indirect costs. On June 5, 2019, Cleco Power and Cabot Corporation each filed separate motions to dismiss. On October 24, 2019, the District Court denied Cleco’s motion as premature and ruled that Saulsbury Industries, Inc. had six weeks to conduct discovery on specified jurisdictional issues. The Magistrate Judge presiding over the Western District of Louisiana consolidated cases issued a report and recommendation to the District Judge that the case instituted by Saulsbury Industries, Inc. be dismissed without prejudice and the case initiated by Cleco Power be remanded to the Ninth Judicial District Court for Rapides Parish. Saulsbury Industries, Inc. did not oppose the Magistrate Judge’s report and recommendation, and the District Judge issued a ruling that adopted the Magistrate Judge’s report and recommendation, which included reasoning consistent with Cleco Power’s arguments. Thus, the federal consolidated cases are now closed.

On October 10, 2019, Cleco Power was served with a summons in Saulsbury Industries, Inc. v. Cabot Corporation and Cleco Power LLC in the 16th Judicial District Court for St. Mary Parish, No. 133910-A. Saulsbury Industries, Inc. asserted the same claim as the Western District Litigation and further asserts claims for payment on an open account. On December 9, 2019, Cleco moved to stay the case, arguing that the Rapides Parish suit should proceed. On February 14, 2020, the court granted Cleco’s motion, which stay order remains in place until lifted. The 16th Judicial District Court for the St. Mary Parish case held a hearing on October 16, 2020, and the judge granted Cleco’s declinatory exceptions of lis pendens. Thus, the St. Mary’s Parish case has been dismissed. Saulsbury filed a motion for a new trial. The hearing on this motion was held on February 5, 2021, and the 16th Judicial District Court judge

denied Saulsbury’s motion for a new trial. Saulsbury has appealed this decision.

LPSC Audits

Fuel Audits

Generally, Cleco Power’s cost of fuel used for electric generation and the cost of purchased power are recovered through the LPSC-established FAC that enables Cleco Power to pass on to its customers substantially all such charges. Recovery of FAC costs is subject to periodic fuel audits by the LPSC. The LPSC FAC General Order issued in November 1997, in Docket No. U-21497 provides that an audit of FAC filings will be performed at least every other year. In March 2020, Cleco Power received a notice of audit from the LPSC for the period of January 2018 to December 2019. The total amount of fuel expense included in the audit is $565.8 million. Cleco Power has responded to several sets of data requests from the LPSC. Cleco Power has FAC filings for January 2020 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. Historically, the disallowances have not been material. If a disallowance of fuel cost is ordered resulting in a refund, any such refund could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.

On March 29, 2021, Cleco Power received approval from the LPSC to recover $50.0 million of incremental fuel and purchased power costs incurred as a result of Winter Storms Uri and Viola over a period of 12 months beginning in May 2021. On May 11, 2021, Cleco Power received notice of an audit from the LPSC for the fuel costs incurred during the time period required to restore services to Cleco Power’s customers during Winter Storms Uri and Viola. Management is unable to determine the outcome or timing of the audit. For more information on these winter storms, see Note 17 — “Storm Restoration — Winter Storms Uri and Viola.”

Environmental Audit

In 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides Cleco Power an EAC to recover from its customers certain costs of environmental compliance. The costs eligible for recovery are those for prudently incurred air emissions credits associated with complying with federal, state, and local air emission regulations that apply to the generation of electricity reduced by the sale of such allowances. Also eligible for recovery are variable emission mitigation costs, which are the costs of reagents such as ammonia and limestone that are a part of the fuel mix used to reduce air emissions, among other things. In March 2020, Cleco Power received notice from the LPSC of the EAC audit for the period of January 2018 to December 2019. The total amount of environmental expense included in the audit is $26.2 million. Cleco Power has responded to several sets of data requests from the LPSC. Cleco Power has EAC filings for January 2020 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. Historically, the disallowances have not been material. If a disallowance of environmental cost is ordered resulting in a refund to Cleco Power’s customers, any such refund could have a material adverse effect on the results

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of operations, financial condition, or cash flows of the Registrants.

Cleco Power incurs environmental compliance expenses for reagents associated with the compliance standards of Mercury and Air Toxics Standards (MATS). These expenses are also eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC. In May 2020, the EPA finalized a rule that concluded that it is not appropriate and necessary to regulate hazardous air pollutants from coal- and oil-fired electric generating units. However, the EPA concluded that coal- and oil-fired electric generating units would not be removed from the list of regulated sources of hazardous air pollutants and would remain subject to MATS. The EPA also determined that the results of its risk and technology review did not require any revisions to the emissions standards. Several petitions for review of the rule’s findings were filed between May and July 2020 in the D.C. Circuit Court of Appeals. On January 20, 2021, the new Administration issued an executive order, which directs federal agency heads to review regulations and other actions over the past four years to determine if they are inconsistent with the policies announced in the executive order. The order specifically directs the EPA to consider issuing a proposed rule by August 2021 to suspend, revise, or rescind the rule. The EPA determined the most environmentally protective course is to implement the rules in the executive order. Management is unable to determine whether the outcome of the D.C. Circuit Court of Appeals review or the EPA’s review of the rule as a result of the executive order will result in changes to the MATS standards.

FERC Audit

Generally, Cleco Power records wholesale transmission revenue through approved formula rates, Attachment O of the MISO tariff and certain grandfathered agreements. The calculation of the rate formulas, as well as FERC accounting and reporting requirements, are subject to periodic audits by FERC. In March 2018, the Division of Audits and Accounting, within the Office of Enforcement of FERC, initiated an audit of Cleco Power for the period of January 1, 2014, through June 30, 2019. On September 27, 2019, Cleco Power received the final audit report, which indicated 12 findings of noncompliance with a combination of FERC accounting and reporting requirements and computation of revenue requirements along with 59 recommendations associated with the audit period. Cleco Power submitted a plan for implementing the audit recommendations on October 28, 2019. Cleco Power also submitted the refund analysis on November 7, 2019, which resulted in a refund related to the FERC audit findings, pending final assessment by the FERC Division of Audits and Accounting, which is expected in the third quarter of 2021. As of June 30, 2021, the estimated refund of $4.4 million was fully refunded to Cleco Power’s wholesale transmission customers as a combination of refund payments and a reduction in Attachment O of the MISO tariff and grandfathered agreement rates over the preceding 12 months.

Transmission ROE

Two complaints were filed with FERC seeking to reduce the ROE component of the transmission rates that MISO transmission owners, including Cleco, may collect under the MISO tariff. The complaints sought to reduce the 12.38% ROE used in MISO’s transmission rates to a proposed 6.68%. The

complaints covered the period December 2013 through May 2016. In June 2016, an administrative law judge issued an initial decision in the second rate case docket recommending a 9.70% base ROE. In September 2016, FERC issued a Final Order in response to the first complaint establishing a 10.32% ROE. However, on November 21, 2019, FERC voted to adopt a new methodology for evaluating base ROE for public utilities under the Federal Power Act. In addition, FERC set the MISO transmission owners’ region-wide base ROE at 9.88% for the refund period covered in the first complaint and going forward. The draft FERC order further found that complainants in the second complaint proceeding failed to show that the 9.88% base ROE was unjust and unreasonable and thus dismissed the second complaint. On May 21, 2020, FERC issued Opinion No. 569-A, which granted rehearing in part of Opinion No. 569, which had revised FERC’s methodology for analyzing the base ROE component of public utility rates under section 206 of the Federal Power Act. Opinion No. 569-A further refines FERC’s ROE methodology and finds that the MISO Transmission Owners’ base ROE should be set at 10.02% instead of 9.88%. Cleco Power is unable to determine when a final FERC Order will be issued. As of June 30, 2021, Cleco Power had $0.3 million accrued for the change in the ROE.

In November 2014, the MISO transmission owners committee, of which Cleco is a member, filed a request with FERC for an incentive to increase the new ROE by 50 basis points for RTO participation as allowed by the MISO tariff. In January 2015, FERC granted the request. The collection of the adder was included in MISO’s transmission rates for a total ROE of 10.38% and 10.52% beginning January 1, 2020, and June 1, 2020, respectively.

South Central Generating

In 2017, Louisiana Generating received insurance settlement proceeds for costs incurred to resolve a lawsuit which was brought by the EPA and the Louisiana Department of Environmental Quality against Louisiana Generating related to Big Cajun II, Unit 3. Entergy Gulf States, as co-owner of Big Cajun II, Unit 3, is expected to be allocated a portion of the insurance settlement proceeds. Any amount allocated to Entergy Gulf States will be determined by ongoing litigation and negotiations. South Central Generating estimated this amount to be $10.0 million. As part of the Cleco Cajun Transaction, Cleco Cajun assumed the $10.0 million contingent liability and NRG Energy indemnified Cleco for losses associated with this litigation matter. As a result, Cleco also recorded a $10.0 million indemnification asset in Other current assets on Cleco’s Condensed Consolidated Balance Sheets as part of the Cleco Cajun Transaction.

Prior to the Cleco Cajun Transaction, South Central Generating was involved in various litigation matters, including environmental and contract proceedings, before various courts regarding matters arising out of the ordinary course of business. As of June 30, 2021, management estimates potential losses to be $1.5 million with respect to one of these matters. Management is unable to estimate any potential losses Cleco Cajun may be ultimately responsible for with respect to any of the remaining matters. As part of the Cleco Cajun Transaction, NRG Energy indemnified Cleco for losses as of the closing date associated with matters that existed as of the closing date, including pending litigation.

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Other

Cleco is involved in various litigation matters, including regulatory, environmental, and administrative proceedings before various courts, regulatory commissions, arbitrators, and governmental agencies regarding matters arising in the ordinary course of business. The liability Cleco may ultimately incur with respect to any one of these matters may be in excess of amounts currently accrued. Management regularly analyzes current information and, as of June 30, 2021, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters are $3.8 million and has accrued this amount.

Off-Balance Sheet Commitments and Guarantees

Cleco Holdings and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Holdings’ subsidiaries and equity investees (affiliates). Cleco Holdings and Cleco Power have also agreed to contractual terms that require the Registrants to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees.

Cleco Holdings entered into these off-balance sheet commitments in order to entice desired counterparties to contract with its affiliates by providing some measure of credit assurance to the counterparty in the event Cleco’s affiliates do not fulfill certain contractual obligations. If Cleco Holdings had not provided the off-balance sheet commitments, the desired counterparties may not have contracted with Cleco’s affiliates, or may have contracted with them at terms less favorable to its affiliates.

The off-balance sheet commitments are not recognized on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets because management has determined that Cleco and Cleco Power’s affiliates are able to perform the obligations under their contracts and that it is not probable that payments by Cleco or Cleco Power will be required.

Cleco Holdings provided guarantees and indemnities to Entergy Louisiana and Entergy Gulf States as a result of the sale of the Perryville generation facility in 2005. The remaining indemnifications relate to environmental matters that may have been present prior to closing. These remaining indemnifications have no time limitations. The maximum amount of the potential payment to Entergy Louisiana and Entergy Gulf States is $42.4 million. Management does not expect to be required to pay Entergy Louisiana and Entergy Gulf States under these guarantees.

On behalf of Acadia, Cleco Holdings provided guarantees and indemnifications as a result of the sales of Acadia Unit 1 to Cleco Power and Acadia Unit 2 to Entergy Louisiana in 2010 and 2011, respectively. The remaining indemnifications relate to the fundamental organizational structure of Acadia. These remaining indemnifications have no time limitations or maximum potential future payments. Management does not expect to be required to pay Cleco Power or Entergy Louisiana under these guarantees.

Cleco Holdings provided indemnifications to Cleco Power as a result of the transfer of Coughlin to Cleco Power in March 2014. Cleco Power also provided indemnifications to Cleco Holdings and Evangeline as a result of the transfer of Coughlin to Cleco Power. The maximum amount of the potential payment to Cleco Power, Cleco Holdings, and Evangeline for their respective indemnifications is $40.0 million, except for indemnifications relating to the fundamental organizational

structure of each respective entity, of which the maximum amount is $400.0 million. Management does not expect to be required to make any payments under these indemnifications.

As part of the Amended Lignite Mining Agreement, Cleco Power and SWEPCO, joint owners of the Dolet Hills Power Station, have agreed to pay the loan and lease principal obligations of the lignite miner, DHLC, when due if DHLC does not have sufficient funds or credit to pay. Any amounts paid on behalf of the miner would be credited by the lignite miner against future invoices for lignite delivered. As of June 30, 2021, the maximum projected payment by Cleco Power under this guarantee is estimated to be $25.0 million; however, the Amended Lignite Mining Agreement does not contain a cap. The projection is based on the forecasted loan and lease obligations to be incurred by DHLC, primarily for purchases of equipment. Cleco Power has the right to dispute the incurrence of loan and lease obligations through the review of the mining plan before the incurrence of such loan and lease obligations. In April 2020, Cleco Power and SWEPCO mutually agreed to not develop additional mining areas for future lignite extraction and subsequently provided notice to the LPSC of the intent to cease mining at the Dolet Hills and Oxbow mines by June 2020. The mine closures are subject to LPSC review and approval. As of December 31, 2020, all lignite reserves intended to be extracted from the Oxbow mine had been extracted. On October 6, 2020, Cleco Power and SWEPCO made a joint filing with the LPSC seeking authorization to close the Oxbow mine and to include and defer certain accelerated mine closing costs in fuel and related ratemaking treatment. On March 19, 2021, the LPSC approved the establishment of a regulatory asset for the deferral of certain accelerated mine costs in fuel and related ratemaking treatment. Cleco Power is currently responding to data requests related to the joint filing. The Amended Lignite Mining Agreement does not affect the amount the Registrants can borrow under their credit facilities. Currently, management does not expect to be required to pay DHLC under this guarantee.

Cleco Holdings, in relation to Cleco Cajun’s participation in MISO, and Cleco Power have letters of credit to MISO pursuant to energy market requirements. The letters of credit automatically renew each year and have no impact on Cleco Holdings’ or Cleco Power’s revolving credit facility. In February 2021, as a result of Winter Storms Uri and Viola, Cleco Power and Cleco Holdings, on behalf of Cleco Cajun, were required to post collateral with MISO. In March 2021, Cleco Power and Cleco Cajun settled with MISO the purchased power obligations associated with Winter Storms Uri and Viola. MISO returned associated collateral postings of $24.9 million and $6.5 million to Cleco Power and Cleco Holdings, respectively. For more information on these winter storms, see Note 17 — “Storm Restoration — Winter Storms Uri and Viola.”

Generally, neither Cleco Holdings nor Cleco Power has recourse that would enable them to recover amounts paid under their guarantee or indemnification obligations. There are no assets held as collateral for third parties that either Cleco Holdings or Cleco Power could obtain and liquidate to recover amounts paid pursuant to the guarantees or indemnification obligations.

Other Commitments

Cleco has accrued for liabilities related to third parties, employee medical benefits, and AROs.

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Risks and Uncertainties

Cleco could be subject to possible adverse consequences if Cleco’s counterparties fail to perform their obligations or if Cleco or its affiliates are not in compliance with loan agreements or bond indentures.

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows.

Changes in the regulatory environment or market forces could cause Cleco to determine its assets have suffered an other-than-temporary decline in value, whereby an impairment would be required, and Cleco’s financial condition could be materially adversely affected.

Cleco Power and Cleco Cajun are participants in the MISO market. Energy prices in the MISO market are based on LMP, which includes a component directly related to congestion on the transmission system. Pricing zones with greater transmission congestion may have higher LMPs. Physical transmission constraints present in the MISO market could increase energy costs within pricing zones. Cleco Power and Cleco Cajun use FTRs to mitigate transmission congestion price risks. Changes to anticipated transmission paths may result in an unexpected increase in energy costs.

On March 1, 2019, Cleco Power began to operate the Dolet Hills Power Station from June through September of each year; however, the Dolet Hills Power Station will continue to be available to operate in other months, if needed. In June 2020, after thorough evaluation, management decided to retire the Dolet Hills Power Station.

Cleco Power anticipates filing an application in the third quarter of 2021 with the LPSC giving notice that the Dolet Hills Power Station will be retired at the end of 2021.

In June 2020, Cleco Power remeasured its ARO liabilities due to the expected retirement of the Dolet Hills Power Station. Cleco Power’s ARO liability increased $3.3 million as a result of this remeasurement. At June 30, 2021, Cleco Power’s undivided interest in the Dolet Hills Power Station was $62.6 million and was included in base rates.

In April 2020, Cleco Power and SWEPCO mutually agreed to not develop additional mining areas for future lignite extraction and subsequently provided notice to the LPSC of the intent to cease mining at the Dolet Hills and Oxbow mines by June 2020, subject to LPSC review and approval. As of December 31, 2020, all lignite reserves intended to be extracted from the Oxbow mine had been extracted. On October 6, 2020, Cleco Power and SWEPCO made a joint filing with the LPSC seeking authorization to close the Oxbow mine, and to include and defer certain accelerated mine closing costs in fuel and related ratemaking treatment. The expected early closure of the mines has resulted in increased costs that will be billed through the fuel adjustment clause, which management currently believes are recoverable. Management does not believe the early closure of the mines will have an adverse impact on the recovery value of the Dolet Hills Power Station. On March 19, 2021, the LPSC approved the establishment of a regulatory asset for the deferral of certain accelerated mine costs in fuel and related ratemaking treatment. Cleco Power expects to have sufficient lignite fuel available to continue seasonal operations of the Dolet Hills Power Station through the end of 2021. Cleco Power is currently responding to data requests related to the joint filing.

Fuel costs incurred by the Dolet Hills Power Station are recoverable by Cleco Power through active fuel adjustment clauses. Under the Amended Lignite Mining Agreement, DHLC

bills Cleco Power its proportionate share of incurred lignite extraction and associated mining-related costs as fuel is delivered. As of June 30, 2021, DHLC estimates $96.1 million of costs will be billed to Cleco Power prior to the closure of the Dolet Hills Power Station. In 2009, Cleco Power acquired an interest in Oxbow, which owns mineral rights and land leases. Under a joint operating agreement pertaining to the Oxbow mineral rights and land leases, Oxbow bills Cleco Power its proportionate share of incurred costs. As of June 30, 2021, Oxbow estimates approximately $6.6 million of costs will be billed to Cleco Power prior to the closure of the Dolet Hills Power Station. If any of these costs are not recoverable, it could materially impact the Registrants’ results of operations, financial condition, or cash flows.

Note 14 — Affiliate Transactions

At June 30, 2021, and December 31, 2020, Cleco Holdings had an affiliate receivable of $2.7 million and $1.7 million, respectively, from Cleco Group primarily for franchise taxes. At both June 30, 2021, and December 31, 2020, Cleco Holdings had an affiliate payable of $41.3 million to Cleco Group primarily for settlement of taxes payable. At both June 30, 2021, and December 31, 2020, Cleco Power had an affiliate payable to Cleco Holdings for $57.7 million, of which $57.6 million was for settlement of taxes payable.

Cleco Power has balances that are payable to or due from its affiliates. The following table is a summary of those balances:

	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	10,383	$	57,696	$	10,353	$	57,713
Support Group	1,707		12,737		3,248		14,355
Cleco Cajun	936		4		1,004		—
Total	$	13,026	$	70,437	$	14,605	$	72,068

Oxbow bills Cleco Power its proportionate share of incurred costs related to mineral rights and land leases. These costs are included in fuel inventory and are recoverable from Cleco Power customers through the LPSC-established FAC or related wholesale contract provisions. During the three and six months ended June 30, 2021, Cleco Power recorded $0.9 million and $1.9 million, respectively, of its proportionate share of incurred costs. During the three and six months ended June 30, 2020, Cleco Power recorded $14.6 million and $15.5 million, respectively, of its proportionate share of incurred costs. At both June 30, 2021, and December 31, 2020, Cleco Power had $0.3 million payable to Oxbow. For more information on Cleco Power’s variable interest in Oxbow, see Note 12 — “Variable Interest Entities.”

Note 15 — Intangible Assets and Liabilities

During 2008, Cleco Katrina/Rita acquired a $177.5 million intangible asset which includes $176.0 million for the right to bill and collect storm recovery charges from customers of Cleco Power and $1.5 million of financing costs. This intangible asset was fully amortized in March 2020 and had no residual value at the end of its life.

As a result of the 2016 Merger, fair value adjustments were recorded on Cleco’s Condensed Consolidated Balance Sheet for the valuation of the Cleco trade name and long-term

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wholesale power supply agreements. At the end of their lives, these intangible assets will have no residual value. The trade name intangible asset is being amortized over its estimated economic useful life of 20 years. The intangible assets related to the power supply agreements are amortized over the estimated life of each applicable contract ranging between 7 and 19 years, and the amortization is included in Electric operations on Cleco’s Condensed Consolidated Statements of Income.

As a result of the Cleco Cajun Transaction, fair value adjustments were recorded on Cleco’s Condensed Consolidated Balance Sheet for the difference between the contract and market price of acquired long-term wholesale power agreements. At the end of their lives, these intangible assets and liabilities will have no residual value. These intangibles are amortized over the estimated life of each applicable contract ranging between 2 and 8 years. The amortization is included in Electric operations on Cleco’s Condensed Consolidated Statements of Income.

As part of the Cleco Cajun Transaction, Cleco assumed an LTSA for maintenance services related to the Cottonwood Plant. This intangible liability is being amortized using the straight-line method over the estimated life of the LTSA of seven years. The amortization is included as a reduction to the LTSA prepayments on Cleco’s Condensed Consolidated Balance Sheet.

The following tables present Cleco and Cleco Power’s amortization of intangible assets and liabilities:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Intangible assets
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	—	$	—	$	—	$	517
Trade name	$	64	$	64	$	128	$	128
Power supply agreements	$	6,400	$	6,400	$	12,800	$	12,800
Intangible liabilities
LTSA	$	871	$	871	$	1,742	$	1,742
Power supply agreements	$	718	$	882	$	1,600	$	1,764

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	—	$	—	$	—	$	517

The following tables summarize the balances for intangible assets and liabilities subject to amortization for Cleco:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Intangible assets
Trade name	$	5,100	$	5,100
Power supply agreements	184,004		184,004
Total intangible assets carrying amount	189,104		189,104
Intangible liabilities
LTSA	24,100		24,100
Power supply agreements	14,200		14,200
Total intangible liability carrying amount	38,300		38,300
Net intangible assets carrying amount	150,804		150,804
Accumulated amortization	(73,517)		(63,932)
Net intangible assets subject to amortization	$	77,287	$	86,872

Note 16 — Accumulated Other Comprehensive Loss

The components of accumulated other comprehensive loss are summarized in the following tables for Cleco and Cleco Power. All amounts are reported net of income taxes. Amounts in parentheses indicate debits.

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30, 2021		FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(25,168)	$	(25,796)
Amounts reclassified from AOCI
Amortization of postretirement benefit net (gain) loss	(420)		208
Balances, June 30, 2021	$	(25,588)	$	(25,588)

	FOR THE THREE MONTHS ENDED JUNE 30, 2020		FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(17,099)	$	(17,513)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	442		856
Balances, June 30, 2020	$	(16,657)	$	(16,657)

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2021						FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI		POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(18,681)	$	(5,550)	$	(24,231)	$	(19,139)	$	(5,614)	$	(24,753)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	287		—		287		745		—		745
Reclassification of net loss to interest charges	—		64		64		—		128		128
Balances, June 30, 2021	$	(18,394)	$	(5,486)	$	(23,880)	$	(18,394)	$	(5,486)	$	(23,880)

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	FOR THE THREE MONTHS ENDED JUNE 30, 2020						FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI		POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(16,291)	$	(5,804)	$	(22,095)	$	(16,717)	$	(5,868)	$	(22,585)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	419		—		419		845		—		845
Reclassification of net loss to interest charges	—		64		64		—		128		128
Balances, June 30, 2020	$	(15,872)	$	(5,740)	$	(21,612)	$	(15,872)	$	(5,740)	$	(21,612)

Note 17 — Storm Restoration

Hurricanes Laura, Delta, and Zeta

In August and October 2020, Cleco Power’s distribution and transmission systems sustained substantial damage from three separate hurricanes.

Cleco Power’s total storm restoration costs related to the hurricanes is approximately $243.0 million. The damage to equipment from the hurricanes required replacement, as well as repair of existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 63%, or approximately $152.4 million, of the total restoration costs recorded at June 30, 2021. At June 30, 2021, Cleco Power had regulatory assets for non-capital expenses related to Hurricanes Laura, Delta, and Zeta, as allowed by the LPSC, totaling $77.7 million.

On December 4, 2020, Cleco Power filed an application with the LPSC requesting an interim rate recovery for return on certain storm restoration costs associated with the hurricanes until securitization of such costs can be completed. On May 19, 2021, the LPSC issued an order authorizing Cleco Power to recover $16.0 million annually for interim storm recovery costs. This order is effective until such time that the LPSC issues its order authorizing the recovery of the verified final storm costs and securitization of those costs. Cleco Power began collecting this amount through rates on June 1, 2021.

On August 5, 2021, Cleco Power filed testimony with the LPSC relating to securitization of the final storm costs for Hurricanes Laura, Delta, and Zeta.

Cleco Power, in line with other impacted utilities, will seek available funds from the U.S. government for relief of costs incurred from Hurricanes Laura, Delta, and Zeta. Cleco Power cannot predict the likelihood that any reimbursement from the U.S. government ultimately will be approved.

Winter Storms Uri and Viola

In February 2021, Winter Storms Uri and Viola reached Louisiana causing Cleco’s service territories to experience extreme and unprecedented winter weather that resulted in

damage to Cleco Power’s distribution assets, electricity generation supply shortages, natural gas supply shortages, and increases in wholesale prices of natural gas in the United States, primarily due to prolonged freezing temperatures. Cleco Power’s current estimate of the total storm restoration costs related to Winter Storms Uri and Viola is approximately $10.5 million. The damage to equipment from the storms required replacement, as well as repair of the existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 80%, or approximately $8.4 million, of the estimated total restoration costs recorded at June 30, 2021. At June 30, 2021, Cleco Power had a regulatory asset for the remaining operations and maintenance costs of $2.0 million, as allowed by the LPSC. Cleco Power has requested recovery of these costs through the storm securitization filing that was made with the LPSC on August 5, 2021.

Cleco Power’s incremental fuel and purchased power costs incurred as a result of Winter Storms Uri and Viola is approximately $55.0 million. On March 29, 2021, Cleco Power received approval from the LPSC to recover $50.0 million of these costs over a period of 12 months beginning in May 2021. On May 11, 2021, Cleco Power received notice of an audit from the LPSC for the fuel costs incurred during the time period required to restore services to Cleco Power’s customers during Winter Storms Uri and Viola. Management is unable to determine the outcome or timing of the audit.

Cleco Cajun's incremental negative impact of Winter Storms Uri and Viola on operations is approximately $11.2 million. The incremental impact to Cleco Cajun’s operations is subject to final settlement.

In February 2021, as a result of Winter Storms Uri and Viola, Cleco Power and Cleco Holdings, on behalf of Cleco Cajun, were required to post collateral with MISO. In March 2021, Cleco Power and Cleco Cajun settled with MISO the purchased power obligations associated with Winter Storms Uri and Viola. MISO returned associated collateral postings of $24.9 million and $6.5 million to Cleco Power and Cleco Holdings, respectively.

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

Cleco uses its website, https://www.cleco.com, as a routine channel for distribution of important information, including news releases and financial information. Cleco’s website is the primary source of publicly disclosed news about Cleco. Cleco is providing the address to its website solely for informational purposes and does not intend for the address to be an active link. The contents of the website are not incorporated into this Quarterly Report on Form 10-Q.

The following discussion and analysis should be read in combination with the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020, and Cleco and Cleco Power’s Condensed Consolidated Financial Statements contained in this Quarterly Report on Form 10-Q. The information included therein is essential to understanding the following discussion and analysis. Below is information concerning the consolidated results of operations of Cleco for the three and six months ended June 30, 2021, and 2020.

OVERVIEW

Cleco is a regional energy company that conducts substantially all of its business operations through its two principal operating business segments:

•Cleco Power, a regulated electric utility company that owns 10 generating units with a total rated capacity of 3,360 MW and serves approximately 290,000 customers in Louisiana through its retail business and supplies wholesale power in Louisiana and Mississippi; and

•Cleco Cajun, an unregulated electric utility company that owns 14 generating units with a total rated capacity of 3,379 MW and wholesale contracts serving nine Louisiana cooperatives, two wholesale municipal customers, and one electric utility. Upon the closing of the Cleco Cajun Transaction, Cottonwood Energy entered into the Cottonwood Sale Leaseback.

Significant Events

Winter Storms Uri and Viola

In February 2021, Winter Storms Uri and Viola reached Louisiana causing Cleco’s service territories to experience extreme and unprecedented winter weather that resulted in damage to Cleco Power’s distribution assets, electricity generation supply shortages, natural gas supply shortages, and increases in wholesale prices of natural gas in the United States, primarily due to prolonged freezing temperatures.

Cleco Power’s current estimate of the total storm restoration costs related to Winter Storms Uri and Viola is approximately $10.5 million. The damage to equipment from the storms required replacement, as well as repair of existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 80%, or approximately $8.4 million, of the estimated total restoration costs recorded at June 30, 2021. At June 30, 2021, Cleco Power had a regulatory asset for the remaining operations and maintenance costs of $2.0 million, as allowed by the LPSC. Cleco Power has requested recovery of these costs through the storm securitization filing that was made with the LPSC on August 5, 2021.

Cleco Power’s incremental fuel and purchased power costs incurred as a result of Winter Storms Uri and Viola is

approximately $55.0 million. On March 29, 2021, Cleco Power received approval from the LPSC to recover $50.0 million of these costs over a period of 12 months beginning in May 2021. On May 11, 2021, Cleco Power received notice of an audit from the LPSC for fuel costs incurred during the time period required to restore services to Cleco Power’s customers during Winter Storms Uri and Viola. Management is unable to determine the outcome or timing of the audit.

Cleco Cajun’s incremental negative impact of Winter Storms Uri and Viola on operations is approximately $11.2 million. The incremental impact to Cleco Cajun’s operations is subject to final settlement.

In February 2021, as a result of Winter Storms Uri and Viola, Cleco Power and Cleco Holdings, on behalf of Cleco Cajun, were required to post collateral with MISO. In March 2021, Cleco Power and Cleco Cajun settled with MISO the purchased power obligations associated with Winter Storms Uri and Viola. MISO returned associated collateral postings of $24.9 million and $6.5 million to Cleco Power and Cleco Holdings, respectively.

For more information on Winter Storms Uri and Viola, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 17 — Storm Restoration — Winter Storms Uri and Viola.”

Hurricanes Laura, Delta, and Zeta

In August and October 2020, Cleco Power’s distribution and transmission systems sustained substantial damage from three separate hurricanes.

Cleco Power’s total storm restoration costs related to the hurricanes is approximately $243.0 million. The damage to equipment from the hurricanes required replacement, as well as repair of existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 63%, or approximately $152.4 million, of the total restoration costs recorded at June 30, 2021. At June 30, 2021, Cleco Power had regulatory assets for non-capital expenses related to Hurricanes Laura, Delta, and Zeta, as allowed by the LPSC, totaling $77.7 million.

On December 4, 2020, Cleco Power filed an application with the LPSC requesting an interim rate recovery for return on certain storm restoration costs associated with the hurricanes until securitization of such costs can be completed. On May 19, 2021, the LPSC issued an order authorizing Cleco Power to recover $16.0 million annually for interim storm recovery costs. This order is effective until such time that the LPSC issues its order authorizing the recovery of the verified final storm costs and securitization of those costs. Cleco Power began collecting this amount through rates on June 1, 2021.

On August 5, 2021, Cleco Power filed testimony with the LPSC relating to securitization of the final storm costs for Hurricanes Laura, Delta, and Zeta.

Cleco Power, in line with other impacted utilities, will seek available funds from the U.S. government for relief of costs incurred from Hurricanes Laura, Delta, and Zeta. Cleco Power cannot predict the likelihood that any reimbursement from the U.S. government ultimately will be approved.

COVID-19

In March 2020, WHO declared the outbreak of COVID-19 to be a global pandemic, and the U.S. declared a national emergency. In response to these declarations and the rapid

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spread of COVID-19, federal, state and local governments imposed varying degrees of restrictions on business and social activities to contain COVID-19. These restrictions significantly impacted many sectors of the economy with record levels of unemployment driven by businesses, nonprofit organizations, and governmental entities modifying, curtailing, or ceasing normal operations. State and local authorities also subsequently implemented multistep policies to reopen various sectors of the economy such as retail establishments, health and personal care businesses, and restaurants, among others. During March and April 2021, due to the reduction in new COVID-19 cases and hospitalizations and the availability of COVID-19 vaccines, the governor of the state of Louisiana reduced restrictions that were previously in effect, eased capacity limits on businesses and social gatherings, and revoked the mandatory, state-wide mask mandate. However, effective August 4, 2021, the state-wide mask mandate was reinstated due to a surge in COVID-19 cases.

Cleco is monitoring the ongoing COVID-19 pandemic and continues to adjust certain business practices to conform to government restrictions and best practices encouraged by the CDC, WHO, and other governmental and regulatory authorities. The first priority in Cleco’s response to this crisis has been the health and safety of its employees, its customers, and other business counterparties. Cleco has implemented preventative measures and developed corporate response plans to minimize unnecessary risk of exposure and prevent infection, while supporting its customers’ operations to the best of its ability in the circumstances.

Beginning on March 13, 2020, and as a result of an LPSC executive order, Cleco Power suspended the assessment of late fees, disconnections, and the utilization of collection agencies to help customers facing financial challenges related to the COVID-19 pandemic. Cleco resumed disconnections and late fees beginning October 1, 2020, as allowed by the LPSC. On December 4, 2020, Cleco Power made a filing with the LPSC requesting the recovery of the regulatory asset as well as the lost revenue associated with the disconnection fees and incremental costs. At June 30, 2021, Cleco Power had a regulatory asset of $3.0 million for expenses incurred. Cleco expects LPSC approval for the recovery of the regulatory asset in September 2021.

Cleco is also working with its suppliers to understand the potential impacts to its supply chain. Cleco will continue to monitor developments affecting its workforce, customers, and suppliers and take additional precautions as Cleco deems warranted.

Cleco has implemented certain measures that it believes will provide financial flexibility and help maintain its liquidity, including drawing on Cleco Holdings’ and Cleco Power’s revolving credit facilities. At June 30, 2021, there was no balance outstanding on Cleco Holdings’ revolving credit facility and $160.0 million outstanding on Cleco Power’s revolving credit facility. While Cleco continues to assess the COVID-19 situation, Cleco cannot predict the full impact that COVID-19 or the significant disruption and volatility currently being experienced in the markets will have on its business, cash flows, liquidity, financial condition, and results of operations. For additional discussion regarding certain risks associated with the COVID-19 pandemic, see Part I, Item 1A, “Risk Factors — Operational Risks — COVID-19” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

American Jobs Act of 2021

On March 31, 2021, the President announced the American Jobs Act. This proposal includes a number of incentives to encourage construction of certain transmission and energy storage property. The proposed act also proposes to raise the federal statutory corporate income tax rate from 21% to 28% and to introduce a minimum tax based on book income. Currently, management is unable to predict the impact of the proposed act on the Registrants.

Cleco Power

Many factors affect Cleco Power’s primary business of generating, delivering, and selling electricity. These factors include weather and the presence of a stable regulatory environment, which impacts the ROE, as well as the recovery of costs related to storms, growing energy demand, and rising fuel prices; the ability to increase energy sales while containing costs; the ability to reliably deliver power to its jurisdictional customers; the ability to comply with increasingly stringent regulatory and environmental standards; and the ability to successfully perform in MISO while subject to the related operating challenges and uncertainties, including increased wholesale competition. Cleco Power’s current key initiatives are continuing construction on the Bayou Vista to Segura Transmission project; continuing the DSMART project; and maintaining and growing its wholesale and retail businesses. These and other initiatives are discussed below.

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan. Effective July 1, 2021, under the terms of the new FRP, Cleco Power is allowed to earn a target ROE of 9.5%, while providing the opportunity to earn up to 10.0%. Additionally, 60.0% of retail earnings between 10.0% and 10.5%, and all retail earnings over 10.5%, are required to be refunded to customers. The amount of credits due to customers, if any, is determined by Cleco Power and the LPSC, annually. For more information on the new FRP for Cleco Power, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 11 — Regulation and Rates — FRP.”

Bayou Vista to Segura Transmission Project

The Bayou Vista to Segura Transmission project includes the construction of 48 miles of 230 kilovolt transmission line, a 230/138 kilovolt substation, and three substation expansions in south Louisiana. The project is expected to cost approximately $125.1 million. The project is expected to increase reliability, provide transmission system redundancy, and provide hurricane hardening for customers in south Louisiana. Cleco Power received MISO approval for the project in December 2017. As part of Cleco Power’s new retail rate plan, the LPSC approved the establishment of a regulatory asset and recovery of the revenue requirements associated with the Bayou Vista to Segura Transmission project upon completion of each phase of the project. Construction has already been completed on expansions to existing substations. The northern phase is expected to be completed in the third quarter of 2021, and the southern phase is expected to be completed in the fourth quarter of 2021. As of June 30, 2021, Cleco Power had spent $84.7 million on the project.

DSMART Project

The DSMART project includes modernization of Cleco Power’s distribution system by replacing or upgrading distribution line equipment utilizing new and emerging technologies to facilitate

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automatic fault isolation, service restoration, and fault location. The project is expected to provide savings through a reduction in outage restoration time, time to locate faults, and improved operational efficiencies. The project is also expected to improve safety and reliability of Cleco Power’s distribution assets by minimizing outage patrols and improving situational awareness in the distribution operations center. The total estimated project cost is $90.2 million. The project implementation will be completed in phases and management expects the total project will be completed by the end of 2025. In January 2019, Cleco Power began the first phase of the project. As of June 30, 2021, Cleco Power had spent $25.0 million on the project.

Other

Cleco Power is working to secure load growth opportunities that include renewing existing franchises and wholesale contracts, pursuing new wholesale contracts and franchises, and adding new retail load opportunities with large industrial, commercial, and residential load. The retail opportunities include sectors such as agriculture, oil and gas, chemicals, metals, national accounts, government and military, wood and paper, health care, information technology, transportation, and other manufacturing. Failure to renew existing franchises and wholesale contracts could have a material adverse effect on Cleco Power’s results of operations, financial condition, cash flows, and liquidity.

Cleco Cajun

Cleco Cajun has 12 power purchase agreements totaling approximately 2,100 MW with a mixture of cooperatives, municipal bodies, and a utility. Cleco Cajun routinely seeks to grow the amount of power sold pursuant to these existing agreements. These contracts provide Cleco Cajun with predictable cash flow and market risk mitigation through at least 2025 but may prevent Cleco Cajun from taking advantage of rising market rates for power.

In 2020, a group of cooperatives, which are currently under contract with Cleco Cajun through the first quarter of 2025, conducted a request for proposal for load after 2025 in which Cleco Cajun participated. In March 2021, the group of cooperatives informed Cleco Cajun that it was not selected as a provider of load after the first quarter of 2025 and filed a notice with the LPSC to certify the results of the request for proposal. Cleco Cajun subsequently filed a notice of intervention with the LPSC requesting further review prior to certifying the cooperatives’ notice. The certification process is in the early stages and, on April 20, 2021, the LPSC issued a procedural schedule that extends into the first quarter of 2022. Cleco Cajun will continue to support the process and cannot predict the outcome of the process. Failure to recontract these or other agreements could have a material adverse effect on Cleco Cajun’s results of operations, financial condition, and cash flows.

Many factors affect Cleco Cajun’s primary business of providing wholesale power and capacity. These factors include weather, the market price of power, the sales volume of power through existing contracts, the ability to recontract existing contracts at or before their expiration or enter into new wholesale power agreements with new customers, the ability to comply with increasingly stringent environmental standards, and compliance with the commitments made to the LPSC as a result of the Cleco Cajun Transaction.

RESULTS OF OPERATIONS

Comparison of the Three Months Ended June 30, 2021, and 2020

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2021		2020		VARIANCE		CHANGE
Operating revenue, net	$	378,749	$	357,758	$	20,991	5.9	%
Operating expenses	254,763		267,564		12,801		4.8	%
Operating income	123,986		90,194		33,792		37.5	%
Interest income	829		898		(69)		(7.7)	%
Allowance for equity funds used during construction	1,105		127		978		770.1	%
Other (expense) income, net	(3,970)		257		(4,227)		*
Interest charges	33,291		34,715		1,424		4.1	%
Federal and state income tax expense	9,837		13,593		3,756		27.6	%
Net income	$	78,822	$	43,168	$	35,654	82.6	%
* Not meaningful

Results of operations for Cleco Power and Cleco Cajun are more fully described following the discussion of Cleco’s results of operations.

Operating Revenue, Net

Operating revenue, net increased $21.0 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $23.2 million of higher fuel cost recovery revenue at Cleco Power. Also contributing to the increase was $6.7 million of higher electric operations revenue at Cleco Cajun. These increases were partially offset by $9.7 million of higher electric customer credits at Cleco Power.

Operating Expenses

Operating expenses decreased $12.8 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $47.0 million of lower fuel used for electric generation at Cleco Cajun. Also contributing to the decrease was $3.4 million of lower non-recoverable fuel and purchased power, $2.5 million of lower other operations and maintenance expenses, and $2.1 million of lower taxes other than income taxes at Cleco Power. These decreases were partially offset by $23.1 million of higher recoverable fuel and purchased power at Cleco Power and $15.9 million of higher purchased power at Cleco Cajun.

Other (Expense) Income, Net

Other (expense) income, net increased $4.2 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $3.0 million for the decrease in cash surrender value of certain trust-owned life insurance policies as a result of less favorable market conditions at Cleco Holdings.

Income Taxes

Federal and state income tax expense decreased $3.8 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $9.5 million for the amortization of excess ADIT, $2.1 million for the flow through of state tax benefits, and $0.4 million to record tax expense at the

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projected annual effective tax rate. These decreases were partially offset by $6.4 million for the change in pretax income, excluding AFUDC equity, and $2.0 million of state tax expense.

The estimated annual effective income tax rates used during the second quarter of 2021 and 2020 for Cleco may not be indicative of the full-year income tax rates. For more information on these effective income tax rates, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 9 — Income Taxes — Effective Tax Rates.”

Cleco Power
			FOR THE THREE MONTHS ENDED JUNE 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2021		2020			VARIANCE		CHANGE
Operating revenue
Base	$	164,113	$	163,994		$	119	0.1	%
Fuel cost recovery	98,835		75,649			23,186		30.6	%
Electric customer credits	(18,762)		(9,100)			(9,662)		(106.2)	%
Other operations	16,269		15,904			365		2.3	%
Affiliate revenue	1,224		1,240			(16)		(1.3)	%
Operating revenue, net	261,679		247,687			13,992		5.6	%
Operating expenses
Recoverable fuel and purchased power	98,824		75,756			(23,068)		(30.5)	%
Non-recoverable fuel and purchased power	4,064		7,487			3,423		45.7	%
Other operations and maintenance	52,160		54,667			2,507		4.6	%
Depreciation and amortization	40,933		41,596			663		1.6	%
Taxes other than income taxes	7,314		9,448			2,134		22.6	%
Total operating expenses	203,295		188,954			(14,341)		(7.6)	%
Operating income	58,384		58,733			(349)		(0.6)	%
Interest income	825		755			70		9.3	%
Allowance for equity funds used during construction	1,105		127			978		770.1	%
Other expense, net	(5,700)		(3,423)			(2,277)		(66.5)	%
Interest charges	18,237		18,603			366		2.0	%
Federal and state income tax expense	8,956		9,356			400		4.3	%
Net income	$	27,421	$	28,233		$	(812)	(2.9)	%

The following table shows the components of Cleco Power’s retail and wholesale customer sales related to base revenue:

	FOR THE THREE MONTHS ENDED JUNE 30,
(MILLION kWh)	2021	2020	FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	873	904		(3.4)	%
Commercial	649	636		2.0	%
Industrial	508	453		12.1	%
Other retail	32	30		6.7	%
Total retail	2,062	2,023		1.9	%
Sales for resale	690	722		(4.4)	%
Total retail and wholesale customer sales	2,752	2,745		0.3	%

The following table shows the components of Cleco Power’s base revenue:

	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	78,254	$	79,069		(1.0)	%
Commercial	47,364		47,921			(1.2)	%
Industrial	19,754		19,170			3.0	%
Other retail	2,785		2,670			4.3	%
Total retail	148,157		148,830			(0.5)	%
Sales for resale	15,956		15,164			5.2	%
Total base revenue	$	164,113	$	163,994		0.1	%

Cleco Power’s residential customers’ demand for electricity is largely affected by weather. Weather generally is measured in cooling degree-days and heating degree-days. A cooling degree-day is an indication of the likelihood that a consumer will use air conditioning, while a heating degree-day is an indication of the likelihood that a consumer will use heating. An increase in heating degree-days does not produce the same increase in revenue as an increase in cooling degree-days because alternative heating sources are more readily available, and winter energy is typically priced below the rate charged for energy used in the summer. Normal heating degree-days and cooling degree-days are calculated for a month by separately calculating the average actual heating and cooling degree-days for that month over a period of 30 years.

The following chart shows how cooling degree-days varied from normal conditions and from the prior period. Cleco Power uses weather data provided by the National Oceanic and Atmospheric Administration to determine degree-days.

	FOR THE THREE MONTHS ENDED JUNE 30,
				2021 CHANGE
	2021	2020	NORMAL	PRIOR YEAR		NORMAL
Cooling degree-days	984	998	942	(1.4)	%	4.5	%

Base

Base revenue increased $0.1 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $1.3 million of new interim rate recovery for return on certain storm costs relating to Hurricanes Laura, Delta, and Zeta, partially offset by $1.2 million of lower usage from milder weather.

For information on the effects of future energy sales on the results of operations, financial condition, or cash flows of Cleco Power, see Part I, Item 1A, “Risk Factors — Operational Risks — Future Electricity Sales” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Fuel Cost Recovery/Recoverable Fuel and Purchased Power

Changes in fuel costs historically have not significantly affected Cleco Power’s net income. Generally, fuel and purchased power expenses are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such charges. Approximately 80% of Cleco Power’s total fuel cost during the second quarter of 2021 was regulated by the LPSC. Recovery of FAC costs is subject to periodic fuel audits by the LPSC which may result in

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a refund to customers. Generally, fuel and purchased power expenses are impacted by customer usage, the per unit cost of fuel used for electric generation, and the dispatch of Cleco Power’s generating facilities by MISO. Cleco Power’s incremental fuel and purchased power costs were impacted significantly as a result of Winter Storms Uri and Viola. On March 29, 2021, Cleco Power received approval from the LPSC to recover a portion of these costs through Cleco Power’s FAC over a period of 12 months beginning in May 2021. For more information on Cleco Power’s most current fuel audits, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Fuel Audits.”

Electric Customer Credits

Electric customer credits increased $9.7 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to higher refunds for the federal tax-related benefits of the TCJA. For more information on the TCJA, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 11 — Regulation and Rates — TCJA.”

Non-Recoverable Fuel and Purchased Power

Non-recoverable fuel and purchased power decreased $3.4 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to lower MISO transmission costs.

Other Operations and Maintenance Expense

Other operations and maintenance expense decreased $2.5 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $5.4 million of lower outside services, mostly relating to information technology services and START project expenses, partially offset by $2.8 million of higher distribution maintenance expense.

Taxes Other Than Income Taxes

Taxes other than income taxes decreased $2.1 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to lower property taxes.

Other expense, net

Other expense, net increased $2.3 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $1.0 million for disallowed costs as a result of the rate case, $0.8 million of higher pension non-service costs as a result of a lower discount rate, and $0.4 million for the decrease in cash surrender value of certain company-owned life insurance policies as a result of less favorable market conditions.

Income Taxes

Federal and state income tax expense decreased $0.4 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $9.5 million for the amortization of excess ADIT, $2.1 million for the flow through of state tax benefits, and $0.6 million of state tax expense. These decreases were partially offset by $11.9 million to record tax expense at the projected annual effective tax rate.

The estimated annual effective income tax rates used during the second quarter of 2021 and 2020 for Cleco Power may not be indicative of the full-year income tax rates. For

more information on these effective income tax rates, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 9 — Income Taxes — Effective Tax Rates.”

Cleco Cajun
			FOR THE THREE MONTHS ENDED JUNE 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2021		2020			VARIANCE		CHANGE
Operating revenue
Electric operations	$	91,407	$	84,733		$	6,674	7.9	%
Electric customer credits	244		—			244		100.0	%
Other operations	30,655		30,636			19		0.1	%
Affiliate revenue	—		43			(43)		(100.0)	%
Operating revenue, net	122,306		115,412			6,894		6.0	%
Operating expenses
Fuel used for electric generation	(43,153)		3,798			46,951		*
Purchased power	57,835		41,966			(15,869)		(37.8)	%
Other operations and maintenance	22,113		20,175			(1,938)		(9.6)	%
Depreciation and amortization	11,378		10,346			(1,032)		(10.0)	%
Taxes other than income taxes	3,752		3,791			39		1.0	%
Total operating expenses	51,925		80,076			28,151		35.2	%
Operating income	70,381		35,336			35,045		99.2	%
Interest income	3		103			(100)		(97.1)	%
Other (expense) income, net	(7)		44			(51)		(115.9)	%
Interest charges	(180)		120			300		250.0	%
Federal and state income tax expense	18,063		8,601			(9,462)		(110.0)	%
Net income	$	52,494	$	26,762		$	25,732	96.2	%
* Not meaningful

Electric Operations

Electric operations revenue increased $6.7 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $5.3 million of higher fuel rates, $1.9 million for the absence of a 2020 customer demand adjustment, $1.2 million of higher capacity contract rates, and $0.6 million of higher MISO pass-through recoveries, partially offset by $2.7 million of lower load volumes.

Fuel Used for Electric Generation

Fuel used for electric generation decreased $47.0 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $34.8 million of higher mark-to-market gains on gas related derivative contracts and $7.5 million of settlements related to gas swaps activity. Also contributing to the decrease was $5.0 million of lower fuel expenses largely related to lower gas consumption from higher gas prices, partially offset by higher coal usage.

Purchased Power

Purchased power increased $15.9 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to higher costs of purchased power from MISO.

Other Operations and Maintenance Expense

Other operations and maintenance expense increased $1.9 million during the second quarter of 2021 compared to the

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second quarter of 2020 primarily due to higher generating outage maintenance expense.

Income Taxes

Federal and state income tax expense increased $9.5 million during the second quarter of 2021 compared to the second quarter of 2020 primarily due to $7.4 million for the change in pretax income and $2.4 million for state tax expense.

The effective income tax rates for the second quarters of 2021 and 2020 were 25.6% and 23.4%, respectively. The estimated annual effective income tax rates used during the second quarter of 2021 and 2020 for Cleco Cajun may not be indicative of the full-year income tax rates.

Comparison of the Six Months Ended June 30, 2021, and 2020

Cleco
	FOR THE SIX MONTHS ENDED JUNE 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2021		2020		VARIANCE		CHANGE
Operating revenue, net	$	773,743	$	705,330	$	68,413	9.7	%
Operating expenses	603,459		560,471		(42,988)		(7.7)	%
Operating income	170,284		144,859		25,425		17.6	%
Interest income	1,475		2,054		(579)		(28.2)	%
Allowance for equity funds used during construction	1,991		53		1,938		*
Other expense, net	(7,002)		(12,452)		5,450		43.8	%
Interest charges	67,183		69,863		2,680		3.8	%
Federal and state income tax expense	416		15,155		14,739		97.3	%
Net income	$	99,149	$	49,496	$	49,653	100.3	%
*Not meaningful

Results of operations for Cleco Power and Cleco Cajun are more fully described following the discussion of Cleco’s results of operations.

Operating Revenue, Net

Operating revenue, net increased $68.4 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $61.3 million of higher fuel cost recovery revenue, $4.7 million of higher base revenue, and $3.2 million of higher other operations revenue at Cleco Power. Also contributing to the increase was $19.0 million of higher electric operations income and $2.1 million of higher other operations revenue at Cleco Cajun. These increases were partially offset by $22.3 million of higher electric customer credits at Cleco Power.

Operating Expenses

Operating expenses increased $43.0 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $60.8 million of higher recoverable fuel and purchased power expenses and $2.1 million of higher taxes other than income taxes at Cleco Power. Also contributing to the increase was $38.8 million of higher purchased power expense, $3.5 million of higher other operations and maintenance expense, and $1.8 million of higher depreciation and amortization expense at Cleco Cajun. These increases were partially offset by $5.9 million of lower other operations and maintenance expenses and $2.3 million

of lower depreciation and amortization expense at Cleco Power and $51.9 million of lower fuel expense at Cleco Cajun.

Allowance for equity funds used during construction

Allowance for equity funds used during construction increased $1.9 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to higher AFUDC rates driven by the election of the FERC modified formula authorized in March 2020.

Other Expense, Net

Other expense, net decreased $5.5 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $9.2 million for the increase in the cash surrender value of certain trust-owned life insurance policies as a result of favorable market conditions and $0.9 million of lower SERP non-service costs at Cleco Holdings. Partially offsetting these decreases were $1.9 million of higher pension non-service costs and $1.0 million for disallowed costs as a result of the rate case at Cleco Power.

Interest Charges

Interest charges decreased $2.7 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020. Lower rates on Cleco Holdings’ variable rate debt associated with the 2016 Merger and Cleco Cajun Transaction contributed to $1.3 million and $1.0 million, respectively, of the decrease. Also contributing to the decrease was $0.7 million of lower interest on tax rate refunds. Partially offsetting these decreases was $0.9 million of higher interest associated with Cleco Power’s variable rate bank term loan issued in August 2020.

Income Taxes

Federal and state income tax expense decreased $14.7 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $20.6 million for the amortization of excess ADIT and $3.8 million to record tax expense at the projected annual effective tax rate. These decreases were partially offset by $6.8 million for the change in pretax income, excluding AFUDC equity, and $2.1 million for state tax expense.

The estimated annual effective income tax rates used during the six months ended June 30, 2021, and 2020 for Cleco might not be indicative of the full-year income tax rates. For more information on these effective income tax rates, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 9 — Income Taxes — Effective Tax Rates.”

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Cleco Power
			FOR THE SIX MONTHS ENDED JUNE 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2021		2020		VARIANCE		CHANGE
Operating revenue
Base	$	316,724	$	311,993	$	4,731	1.5	%
Fuel cost recovery	213,383		152,080		61,303		40.3	%
Electric customer credits	(39,738)		(17,440)		(22,298)		(127.9)	%
Other operations	34,895		31,668		3,227		10.2	%
Affiliate revenue	2,879		2,346		533		22.7	%
Operating revenue, net	528,143		480,647		47,496		9.9	%
Operating expenses
Recoverable fuel and purchased power	213,397		152,591		(60,806)		(39.8)	%
Non-recoverable fuel and purchased power	13,734		15,179		1,445		9.5	%
Other operations and maintenance	105,726		111,608		5,882		5.3	%
Depreciation and amortization	83,009		85,273		2,264		2.7	%
Taxes other than income taxes	23,816		21,725		(2,091)		(9.6)	%
Total operating expenses	439,682		386,376		(53,306)		(13.8)	%
Operating income	88,461		94,271		(5,810)		(6.2)	%
Interest income	1,468		1,709		(241)		(14.1)	%
Allowance for equity funds used during construction	1,991		53		1,938		*
Other expense, net	(9,958)		(6,091)		(3,867)		(63.5)	%
Interest charges	36,883		37,184		301		0.8	%
Federal and state income tax (benefit) expense	(767)		12,694		13,461		106.0	%
Net income	$	45,846	$	40,064	$	5,782	14.4	%
* Not meaningful

The following table shows the components of Cleco Power’s retail and wholesale customer sales related to base revenue:

	FOR THE SIX MONTHS ENDED JUNE 30,
(Million kWh)	2021	2020	FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	1,788	1,684		6.2	%
Commercial	1,230	1,218		1.0	%
Industrial	1,028	936		9.8	%
Other retail	64	62		3.2	%
Total retail	4,110	3,900		5.4	%
Sales for resale	1,386	1,372		1.0	%
Total retail and wholesale customer sales	5,496	5,272		4.2	%

The following table shows the components of Cleco Power’s base revenue:

	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	146,065	$	140,959		3.6	%
Commercial	93,829		94,978			(1.2)	%
Industrial	42,181		39,750			6.1	%
Other retail	5,452		5,348			1.9	%
Surcharge	—		2,442			(100.0)	%
Total retail	287,527		283,477			1.4	%
Sales for resale	29,197		28,516			2.4	%
Total base revenue	$	316,724	$	311,993		1.5	%

The following chart shows how cooling and heating degree-days varied from normal conditions and from the prior period. Cleco Power uses weather data provided by the National Oceanic and Atmospheric Administration to determine degree-days.

			FOR THE SIX MONTHS ENDED JUNE 30,
				2021 CHANGE
	2021	2020	NORMAL	PRIOR YEAR		NORMAL
Heating degree-days	985	615	941	60.2	%	4.7	%
Cooling degree-days	1,124	1,262	1,020	(10.9)	%	10.2	%

Base

Base revenue increased $4.7 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $4.8 million of higher usage from colder winter weather, $2.2 million of higher unbilled revenue largely due to colder winter weather, and $1.3 million of new interim rate recovery for return on certain storm costs relating to Hurricanes Laura, Delta, and Zeta. Partially offsetting these increases were the absence of $2.4 million of Cleco Katrina/Rita storm restoration surcharge revenue as a result of the final principal and interest payments on the Cleco Katrina/Rita bonds in March 2020 and $1.2 million of lower revenue related to the St. Mary Clean Energy Center project.

For information on the effects of future energy sales on the results of operations, financial condition, or cash flows of Cleco Power, see Part I, Item 1A, “Risk Factors — Operational Risks — Future Electricity Sales” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Fuel Cost Recovery/Recoverable Fuel and Purchased Power

Changes in fuel costs historically have not significantly affected Cleco Power’s net income. Generally, fuel and purchased power expenses are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such charges. Approximately 73% of Cleco Power’s total fuel cost during the first six months of 2021 was regulated by the LPSC. Recovery of FAC costs is subject to periodic fuel audits by the LPSC which may result in a refund to customers. Generally, fuel and purchased power expenses are impacted by customer usage, the per unit cost of fuel used for electric generation, and the dispatch of Cleco Power’s generating facilities by MISO. Cleco Power’s incremental fuel and purchased power costs were impacted

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significantly as a result of Winter Storms Uri and Viola. On March 29, 2021, Cleco Power received approval from the LPSC to recover a portion of these costs through Cleco Power’s FAC over a period of 12 months beginning in May 2021. For more information on fuel audits, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Fuel Audits.”

Electric Customer Credits

Electric customer credits increased $22.3 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily related to higher refunds for the federal tax-related benefits of the TCJA. For more information on the TCJA, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 11 — Regulation and Rates — TCJA.”

Other Operations Revenue

Other operations revenue increased $3.2 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $2.3 million of higher transmission revenue and $1.0 million of higher reconnection fees.

Non-Recoverable Fuel and Purchased Power

Non-recoverable fuel and purchased power decreased $1.4 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $2.1 million of lower MISO transmission costs, partially offset by $0.8 million of higher fuel costs largely due to the winter storms in 2021.

Other Operations and Maintenance Expense

Other operations and maintenance expense decreased $5.9 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $5.9 million of lower fees for outside services mostly relating to START project expenses, audit services, and consulting expenses, $1.2 million of lower uncollectible expense, $1.0 million of lower generation operation expenses, and $0.8 million of lower distribution operations expense. These decreases were partially offset by $3.1 million of higher distribution maintenance expenses.

Depreciation and Amortization

Depreciation and amortization expense decreased $2.3 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to the absence of amortization of storm damages as a result of the final principal and interest payments on the Cleco Katrina/Rita bonds in March 2020.

Taxes Other Than Income Taxes

Taxes other than income taxes increased $2.1 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $1.1 million of higher property taxes, $0.5 million of higher franchise taxes, and $0.4 million of higher payroll taxes.

Allowance for Equity Funds Used During Construction

Allowance for equity funds used during construction increased $1.9 million during the six months ended June 30, 2021,

compared to the six months ended June 30, 2020, primarily due to higher AFUDC rates driven by the election of the FERC modified formula authorized in March 2020.

Other Expense, Net

Other expense, net increased $3.9 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $1.9 million of higher pension non-service costs as a result of a lower discount rate, $1.0 million for disallowed costs as a result of the rate case, and $0.4 million for the decrease in cash surrender value of certain company-owned life insurance policies as a result of less favorable market conditions.

Income Taxes

Federal and state income tax benefit increased $13.5 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $20.6 million for the amortization of excess ADIT and $2.1 million for the change in pretax income, excluding AFUDC equity. These increases were partially offset by $9.1 million to record tax expense at the projected annual effective tax rate.

The estimated annual effective income tax rates used during the six months ended June 30, 2021, and 2020 for Cleco might not be indicative of the full-year income tax rates. For more information on these effective income tax rates, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 9 — Income Taxes — Effective Tax Rates.”

Cleco Cajun
	FOR THE SIX MONTHS ENDED JUNE 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2021		2020		VARIANCE		CHANGE
Operating revenue
Electric operations	$	192,914	$	173,880	$	19,034	10.9	%
Other operations	63,694		61,597		2,097		3.4	%
Electric customer credits	244		(153)		397		259.5	%
Affiliate revenue	—		204		(204)		(100.0)	%
Operating revenue, net	256,852		235,528		21,324		9.1	%
Operating expenses
Fuel used for electric generation	(32,542)		19,372		51,914		268.0	%
Purchased power	125,443		86,640		(38,803)		(44.8)	%
Other operations and maintenance	44,226		40,688		(3,538)		(8.7)	%
Depreciation and amortization	22,234		20,448		(1,786)		(8.7)	%
Taxes other than income taxes	7,522		7,265		(257)		(3.5)	%
Total operating expenses	166,883		174,413		7,530		4.3	%
Operating income	89,969		61,115		28,854		47.2	%
Interest income	6		258		(252)		(97.7)	%
Other (expense) income, net	(659)		78		(737)		(944.9)	%
Interest charges	(332)		131		463		100.0	%
Federal and state income tax expense	22,673		15,022		(7,651)		(50.9)	%
Net income	$	66,975	$	46,298	$	20,677	44.7	%

Electric Operations

Electric operations revenue increased $19.0 million during the six months ended June 30, 2021, compared to the six months

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ended June 30, 2020, primarily due to $8.9 million of higher fuel rates, $4.9 million of higher MISO make-whole payments, $2.9 million of higher capacity contract rates, $2.8 million of higher load volumes, and $1.3 million for the absence of a 2020 customer demand adjustment. These amounts were partially offset by $2.0 million of lower MISO pass-through recoveries.

Other Operations Revenue

Other operations revenue increased $2.1 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to higher transmission revenue.

Fuel Used for Electric Generation

Fuel used for electric generation decreased $51.9 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $46.6 million of higher mark-to-market gains on gas related derivative contracts and $9.1 million of settlements related to gas swaps activity. These decreases were partially offset by $2.4 million of higher fuel expenses largely the result of higher coal usage, partially offset by lower gas usage.

Purchased Power

Purchased power increased $38.8 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to higher costs of purchased power from MISO.

Other Operations and Maintenance

Other operations and maintenance increased $3.5 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $6.1 million of higher generating outage maintenance expense, partially offset by $3.3 million of lower generation operations expense.

Depreciation and Amortization

Depreciation and amortization increased $1.8 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to normal recurring additions to fixed assets.

Income Taxes

Federal and state income tax expense increased $7.7 million during the six months ended June 30, 2021, compared to the six months ended June 30, 2020, primarily due to $5.9 million for the change in pretax income and $1.8 million for state tax expenses.

The effective income tax rates for the six months ended June 30, 2021, and 2020 were 25.3% and 24.5%, respectively. These estimated annual effective income tax rates for Cleco Cajun may not be indicative of the full-year income tax rates.

Non-GAAP Measure

The financial results in the following tables are presented on an accrual basis. EBITDA is a key non-GAAP financial measure used by the CEO to assess the operating performance of Cleco’s segments; however, it is not indicative of future performance. Management evaluates the performance of Cleco’s segments and allocates resources to them based on segment profit and the requirements to implement strategic initiatives and projects to meet current business objectives. EBITDA is defined as net income adjusted for interest, income taxes, depreciation, and amortization.

The following tables set forth a reconciliation of net income, the nearest comparable GAAP financial performance measure, to EBITDA for the three and six months ended June 30, 2021, and 2020:

	FOR THE THREE MONTHS ENDED JUNE 30,
	2021					2020
(THOUSANDS)	CLECO POWER		CLECO CAJUN			CLECO POWER		CLECO CAJUN
Net income	$	27,421	$	52,494		$	28,233	$	26,762
Add: Depreciation and amortization	40,933		12,339		(1)	41,596		11,143		(2)
Less: Interest income	825		3			755		103
Add: Interest charges	18,237		(180)			18,603		120
Add: Federal and state income tax (benefit) expense	8,956		18,063			9,356		8,601
EBITDA	$	94,722	$	82,713		$	97,033	$	46,523
(1) Includes $3.3 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(2.3) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction. (2) Includes $3.1 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(2.3) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

	FOR THE SIX MONTHS ENDED JUNE 30,
	2021					2020
(THOUSANDS)	CLECO POWER		CLECO CAJUN			CLECO POWER		CLECO CAJUN
Net income	$	45,846	$	66,975		$	40,064	$	46,298
Add: Depreciation and amortization	83,009		23,991		(1)	85,273		22,041		(2)
Less: Interest income	1,468		6			1,709		258
Add: Interest charges	36,883		(332)			37,184		131
Add: Federal and state income tax expense	(767)		22,673			12,694		15,022
EBITDA	$	163,503	$	113,301		$	173,506	$	83,234
(1) Includes $6.4 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(4.6) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction. (2) Includes $6.2 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(4.6) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

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FINANCIAL CONDITION

Liquidity and Capital Resources

General Considerations and Credit-Related Risks

Credit Ratings and Counterparties

Financing for operational needs and capital expenditure requirements not satisfied by operating cash flows depends upon the cost and availability of external funds through both short- and long-term financing. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain or expand its businesses. Access to funds is dependent upon factors such as general economic and capital market conditions, including the impact of COVID-19, regulatory authorizations and policies, Cleco Holdings’ and Cleco Power’s credit ratings, cash flows from routine operations, and credit ratings of project counterparties. After assessing the current operating performance, liquidity, and credit ratings of Cleco Holdings and Cleco Power, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. The following table presents the credit ratings of Cleco Holdings and Cleco Power at June 30, 2021:

	SENIOR UNSECURED DEBT			CORPORATE/LONG-TERM ISSUER
	S&P	MOODY’S	FITCH	S&P	MOODY’S	FITCH
Cleco Holdings	BBB-	Baa3	BBB-	BBB-	Baa3	BBB-
Cleco Power	BBB+	A3	BBB+	BBB+	A3	BBB

Credit ratings are not recommendations to buy, sell, or hold securities, and may be subject to revision or withdrawal at any time by the assigning rating agency. Each rating should be evaluated independently of any other rating.

Cleco Holdings and Cleco Power pay fees and interest under their bank credit agreements based on the highest ratings held. Savings are dependent upon the level of borrowings. If Cleco Holdings’ or Cleco Power’s credit ratings were to be downgraded, Cleco Holdings or Cleco Power, respectively, could be required to pay additional fees and incur higher interest rates for borrowings under their respective revolving credit facilities.

Cleco may be required to provide credit support with respect to any open trading contracts that Cleco has or may initiate in the future. The amount of credit support that Cleco may be required to provide at any point in the future is dependent on the notional value of the initial contract, changes in forward market prices, changes in the volume of open contracts, changes in credit ratings or credit quality where netting agreements take place, and changes in the amount counterparties owe Cleco. Changes in any of these factors could cause the amount of requested credit support to increase or decrease.

Cleco Power and Cleco Cajun participate in the MISO market. MISO requires Cleco Power and Cleco Cajun to provide credit support which may increase or decrease due to the timing of the settlement schedules and MISO margining formulas. In February 2021, as a result of Winter Storms Uri and Viola, Cleco Power and Cleco Holdings, on behalf of Cleco Cajun, were required to post collateral with MISO. In March 2021, Cleco Power and Cleco Cajun settled with MISO the purchased power obligations associated with Winter Storms Uri and Viola. MISO returned associated collateral

postings of $24.9 million and $6.5 million to Cleco Power and Cleco Holdings, respectively. For more information about MISO, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Transmission Rates” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020. For more information about credit support see Item 1, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees.” For more information on Winter Storms Uri and Viola, see Item 1, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 17 — Storm Restoration — Winter Storms Uri and Viola.”

Global and U.S. Economic Environment

Global and domestic economic conditions may have an impact on Cleco’s business and financial condition. Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. During periods of capital market volatility, the availability of capital could be limited and the costs of capital may increase for many companies. Although the Registrants have not experienced restrictions in the financial markets, their ability to access the capital markets may be restricted at a time when the Registrants would like, or need, to do so. Any restrictions could have a material impact on the Registrants’ ability to fund capital expenditures or debt service, or on their flexibility to react to changing economic and business conditions. Credit constraints could have a material negative impact on the Registrants’ lenders or customers, causing them to fail to meet their obligations to the Registrants or to delay payment of such obligations. The lower interest rates to which the Registrants have been exposed have been beneficial to debt issuances; however, these rates have negatively affected interest income for the Registrants’ short-term investments.

TCJA

The provisions of the TCJA reduced the top federal statutory corporate income tax rate from 35% to 21%. As a result of the tax rate reduction, on January 1, 2018, Cleco Power began accruing an estimated reserve for the reduction in the federal statutory corporate income tax rate. In February 2018, the LPSC directed utilities, including Cleco Power, to provide considerations of the appropriate manner to flow through to ratepayers the benefits of the reduction in corporate income taxes as a result of the TCJA. In July 2019, the LPSC approved Cleco Power’s rate refund of $79.2 million, plus interest, for the reduction in the statutory federal tax rate for the period from January 2018 to June 2020. The refund was credited to customers over 12 months beginning August 1, 2019.

In July 2019, the LPSC approved Cleco Power’s motion to address the rate redesign and the regulatory liability for excess ADIT, resulting from the enactment of the TCJA, in Cleco Power’s current base rate case.

As a result of the delay in the rate case, on July 15, 2020, the LPSC approved Cleco Power’s application to extend the TCJA bill credits at the same rate as determined in the initial TCJA refund of approximately $7.0 million per month. The extension was for the period of August 2020 through November 2020. On November 13, 2020, Cleco Power again received approval for its application to extend the TCJA bill credits from November 30, 2020, until such a time that the rate

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case was completed. The $7.0 million monthly refund consisted of approximately $4.4 million, which was to be funded by the unprotected excess ADIT, and approximately $2.6 million, which is the change in the federal statutory corporate income tax rate from 35% to 21%. At June 30, 2021, Cleco Power had $2.1 million accrued for the estimated federal tax-related benefits from the TCJA.

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan which includes the settlement of the TCJA protected and unprotected excess ADIT. Effective July 1, 2021, all retail customers will continue receiving bill credits resulting from the TCJA. The target retail portion of the unprotected excess ADIT is approximately $2.5 million monthly and will be credited over a period of three years concluding on June 30, 2024. The retail portion of the protected excess ADIT will be credited until the full amount of the protected excess ADIT has been returned to Cleco Power’s customers through bill credits. At June 30, 2021, Cleco Power had $324.6 million accrued for the excess ADIT, of which $39.5 million is reflected in current regulatory liabilities.

Fair Value Measurements

Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels. Other financial assets and liabilities are reported at their carrying values at their date of issuance on the consolidated balance sheets with their fair values as of the balance sheet date disclosed within the three levels. For more information about fair value levels, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 6 — Fair Value Accounting.”

Cash Generation and Cash Requirements

Restricted Cash and Cash Equivalents

Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general corporate purposes. For more information on Cleco and Cleco Power’s restricted cash and cash equivalents, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — Restricted Cash and Cash Equivalents.”

Debt

Cleco

At June 30, 2021, Cleco had $160.0 million of short-term debt outstanding under its $475.0 million revolving credit facilities, at an average all-in interest rate of 1.35%. Cleco had $75.0 million of short-term debt outstanding at December 31, 2020.

At June 30, 2021, Cleco’s long-term debt and finance leases outstanding was $3.23 billion, of which $66.7 million was due within one year. The long-term debt due within one year at June 30, 2021, primarily represents $66.0 million of principal payments on Cleco Holdings’ debt as required by the

Cleco Cajun Transaction commitments to the LPSC. Long-term debt decreased by $3.3 million from December 31, 2020.

Cash and cash equivalents available at June 30, 2021, were $78.4 million combined with $315.0 million available revolving credit facility capacity ($175.0 million from Cleco Holdings and $140.0 million from Cleco Power) for total liquidity of $393.4 million. For more information on the credit facility capacity, see “— Credit Facilities.”

At June 30, 2021, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents. In order to mitigate potential credit risk, Cleco and Cleco Power have established guidelines for short-term investments. For more information on the concentration of credit risk through short-term investments classified as cash equivalents, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 6 — Fair Value Accounting.”

At June 30, 2021, and December 31, 2020, Cleco had a working capital surplus of $155.3 million and $140.3 million, respectively. The $15.0 million increase in working capital is primarily due to:

•a $55.1 million increase in fuel inventory primarily due to decreases in usage, as well as higher per unit cost of both lignite and petroleum coke at Cleco Power,

•a $46.2 million increase in accumulated deferred fuel, excluding Cleco Power FTRs, primarily due to additional deferrals through a fuel surcharge at Cleco Power for incremental costs related to Winter Storms Uri and Viola, and

•a $23.1 million increase in energy risk management assets, excluding Cleco Power FTRs, primarily due to market value changes on gas-related derivative contracts.

These increases in working capital were partially offset by:

•an $85.0 million increase in short-term debt due to draws on Cleco Power’s revolving credit facility,

•a $25.0 million increase in taxes payable primarily due to accruals of property taxes,

•a $21.4 million increase in regulatory liabilities primarily due to the reclassification of the short-term portion of the regulatory liability related to the TCJA, partially offset by credits to Cleco Power’s customers for the TCJA refunds, and

•a $10.2 million increase in accounts payable, excluding Cleco Power FTR purchases, primarily due to an increase in solid fuel purchases and an increase in gas prices, partially offset by the short-term incentive plan payments in March 2021 and the timing of property tax payments.

Cleco Holdings

At June 30, 2021, and December 31, 2020 Cleco Holdings had no short-term debt outstanding.

At June 30, 2021, Cleco Holding’s long-term debt outstanding was $1.60 billion, of which $66.0 million was due within one year. The long-term debt due within one year at June 30, 2021, represents principal payments on Cleco Holdings’ debt as required by the Cleco Cajun Transaction commitments to the LPSC.

At June 30, 2021, Cleco Holdings had no borrowings outstanding under its $175.0 million revolving credit facility. For more information on Cleco Holding’s revolving credit facility, see “— Credit Facilities.” Cleco Holdings has an uncommitted line of credit that allows up to $10.0 million in short-term

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borrowings, but no more than $10.0 million in the aggregate with Cleco Power’s similar line of credit, to support its working capital needs. There were no amounts outstanding under the uncommitted line of credit at June 30, 2021.

Cash and cash equivalents available at Cleco Holdings at June 30, 2021, were $6.2 million, combined with $175.0 million revolving credit facility capacity for total liquidity of $181.2 million.

Cleco Power

At June 30, 2021, Cleco Power had $160.0 million of short-term debt outstanding under its $300.0 million revolving credit facility, at an all-in interest rate of 1.35%. For more information on Cleco Power’s revolving credit facility, see “— Credit Facilities.” Cleco Power had $75.0 million short-term debt outstanding at December 31, 2020. Following the restoration efforts for Hurricanes Laura, Delta, and Zeta, Cleco Power believes it has sufficient liquidity to meet its current obligations using a combination of cash on hand and available capacity under its revolving credit facilities. However, Cleco Power continues to explore options to supplement its liquidity until such time securitization of such costs can be completed. For more information on Hurricanes Laura, Delta, and Zeta, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 17 — Storm Restoration.” Cleco Power has an uncommitted line of credit that allows up to $10.0 million in short-term borrowings, but no more than $10.0 million in the aggregate with Cleco Holdings’ similar line of credit, to support their working capital needs. There were no amounts outstanding under the uncommitted line of credit at June 30, 2021.

At June 30, 2021, Cleco Power’s long-term debt outstanding was $1.50 billion, of which $0.7 million was due within one year. For Cleco Power, long-term debt decreased $0.1 million from December 31, 2020.

Cash and cash equivalents available at June 30, 2021, were $20.8 million, combined with $140.0 million revolving credit facility capacity for total liquidity of $160.8 million.

At June 30, 2021, and December 31, 2020, Cleco Power had a working capital deficit of $29.6 million and a surplus of $13.4 million, respectively. The $43.0 million decrease in working capital is primarily due to:

•an $85.0 million increase in short-term debt due to draws on the revolving credit facility,

•a $30.8 million increase in taxes payable primarily due to accruals of property taxes,

•a $25.6 million increase in accounts payable, excluding FTR purchases, primarily due to an increase in solid fuel purchases and an increase in gas prices, partially offset by the short-term incentive plan payments in March 2021 and the timing of property tax payments, and

•a $21.4 million increase in regulatory liabilities primarily due to the reclassification of the short-term portion of the regulatory liability related to the TCJA, partially offset by credits to Cleco Power’s customers for the TCJA refunds.

These decreases in working capital were partially offset by:

•a $56.1 million increase in fuel inventory primarily due to decreases in usage, as well as higher per unit cost of both lignite and petroleum coke and

•a $46.2 million increase in accumulated deferred fuel, excluding FTRs, primarily due to additional deferrals through a fuel surcharge for incremental costs related to Winter Storms Uri and Viola.

Credit Facilities

At June 30, 2021, Cleco had two separate revolving credit facilities, one for Cleco Holdings in the amount of $175.0 million with no outstanding borrowings and one for Cleco Power in the amount of $300.0 million with outstanding borrowings of $160.0 million. These revolving credit agreements were entered into on May 21, 2021, and replaced the respective existing agreements. The total of all revolving credit facilities creates a maximum aggregate capacity of $475.0 million with outstanding borrowings of $160.0 million.

Cleco Holdings’ revolving credit facility provides for working capital and other financing needs. The revolving credit facility includes restrictive financial covenants and expires in May 2026. Under covenants contained in Cleco Holdings’ revolving credit facility, Cleco is required to maintain total indebtedness less than or equal to 65% of total capitalization. At June 30, 2021, Cleco Holdings was in compliance with the covenants of its revolving credit facility. At June 30, 2021, the borrowing costs under the facility were equal to LIBOR plus 1.625% or ABR plus 0.625%, plus commitment fees of 0.275%. If Cleco Holdings’ credit ratings were to be downgraded one level by the credit rating agencies, Cleco Holdings may be required to pay higher fees and additional interest of 0.175% under the pricing levels of its revolving credit facility.

Cleco Power’s revolving credit facility provides for working capital and other financing needs. The revolving credit facility includes restrictive financial covenants and expires in May 2026. Under covenants contained in Cleco Power’s revolving credit facility, Cleco Power is required to maintain total indebtedness less than or equal to 65% of total capitalization. At June 30, 2021, Cleco Power was in compliance with the covenants of its revolving credit facility. At June 30, 2021, the borrowing costs under the facility were equal to LIBOR plus 1.25% or ABR plus 0.25%, plus commitment fees of 0.15%. If Cleco Power’s credit ratings were to be downgraded one level by the credit rating agencies, Cleco Power may be required to pay higher fees and additional interest of 0.15% under the pricing levels of its revolving credit facility.

If Cleco Holdings or Cleco Power were to default under the covenants in their respective revolving credit facilities or other debt agreements, they would be unable to borrow additional funds under the facilities, and the lenders could accelerate all principal and interest outstanding. Further, if Cleco Power were to default under its revolving credit facility or other debt agreements, Cleco Holdings would be considered in default under its revolving credit facility.

Debt and Distribution Limitations

The 2016 Merger Commitments include provisions for limiting the amount of distributions that can be made from Cleco Holdings to Cleco Group, depending on Cleco Holdings’ debt to EBITDA ratio and its corporate credit ratings. Cleco Holdings may not make any distribution unless, after giving effect to such distribution, Cleco Holdings’ debt to EBITDA ratio is equal to or less than 6.50 to 1.00 and Cleco Holdings’ corporate credit rating is investment grade with one or more of the three credit rating agencies. At June 30, 2021, Cleco Holdings was in compliance with the provisions of the 2016 Merger Commitments that would restrict the amount of

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distributions available. Additionally, in accordance with the 2016 Merger Commitments, Cleco Power is subject to certain provisions limiting the amount of distributions that may be paid to Cleco Holdings, depending on Cleco Power’s common equity ratio and its corporate credit ratings. Cleco Power may not make any distribution unless, after giving effect to such distribution, Cleco Power’s common equity ratio would not be less than 48% and Cleco Power’s corporate credit rating is investment grade with two of the three credit rating agencies. At June 30, 2021, Cleco Power was in compliance with the provisions of the 2016 Merger Commitments that would restrict the amount of distributions available. The 2016 Merger Commitments also prohibit Cleco from incurring additional long-term debt, excluding non-recourse debt, unless certain financial ratios are achieved. For more information on the 2016 Merger Commitments, see Part I, Item 1A, “Risk Factors — Structural Risks — Holding Company” and “— Regulatory Risks — Regulatory Compliance” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Cleco Consolidated Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $45.5 million and $95.8 million during the six months ended June 30, 2021, and 2020, respectively. Net cash provided by operating activities decreased $50.3 million primarily due to:

•higher recoverable fuel and purchased power costs primarily associated with Winter Storms Uri and Viola not yet collected from Cleco Power customers of approximately $46.2 million,

•higher operations and maintenance payments related to storm restoration activities of $7.3 million at Cleco Power,

•lower collections from Cleco Cajun’s joint owners of $6.1 million primarily due to timing of receipts for their portions of generating station expenditures,

•lower collections from Cleco Power customers of $4.6 million due to the rate refund for the tax-related benefits from the TCJA, which began being credited to customers in August 2019, and

•the absence of Cleco Katrina/Rita storm restoration surcharge collections from Cleco Power customers of $2.4 million as a result of the final principal and interest payments on the Cleco Katrina/Rita storm recovery bonds in March 2020.

These decreases were partially offset by:

•lower payments for fuel inventory at Cleco Power of $13.4 million primarily due to lower coal and gas purchases,

•lower payments for fuel inventory at Cleco Cajun of $9.6 million due to lower coal purchases, and

•lower payments for employee benefits of $3.0 million.

Net Investing Cash Flow

Net cash used in investing activities was $135.7 million and $138.7 million during the six months ended June 30, 2021, and 2020, respectively. Net cash used in investing activities decreased $3.0 million primarily due to higher distributions of $1.8 million received by Cleco Power from Oxbow.

Net Financing Cash Flow

Net cash provided by financing activities was $82.0 million and $223.2 million during the six months ended June 30, 2021, and 2020, respectively. Net cash provided by financing activities decreased $141.2 million primarily due to lower draws on revolving credit facilities of $138.0 million and higher payments on revolving credit facilities of $15.0 million, partially offset by the absence of the final repayment of Cleco Katrina/Rita storm recovery bonds of $11.1 million.

Cleco Power Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $40.5 million during the six months ended June 30, 2021. Net cash provided by operating activities was $66.5 million during the six months ended June 30, 2020. Net cash provided by operating activities decreased $26.0 million primarily due to:

•higher recoverable fuel and purchased power costs primarily associated with Winter Storms Uri and Viola not yet collected from customers of approximately $46.2 million,

•higher operations and maintenance payments related to storm restoration activities of $7.3 million,

•lower collections from customers of $4.6 million due to the rate refund for the tax-related benefits from the TCJA, which began being credited to customers in August 2019, and

•the absence of Cleco Katrina/Rita storm restoration surcharge collections from customers of $2.4 million as a result of the final principal and interest payments on the Cleco Katrina/Rita storm recovery bonds in March 2020.

These decreases were partially offset by lower payments for fuel inventory of $13.4 million primarily due to lower coal and gas purchases.

Net Investing Cash Flow

Net cash used in investing activities was $129.4 million and $132.0 million during the six months ended June 30, 2021, and 2020, respectively. Net cash used in investing activities decreased $2.6 million primarily due to higher distributions of $1.8 million received from Oxbow.

Net Financing Cash Flow

Net cash provided by financing activities was $83.2 million and $137.5 million during the six months ended June 30, 2021, and 2020, respectively. Net cash provided by financing activities decreased $54.3 million primarily due to lower draws on revolving credit facilities of $50.0 million and higher payments on revolving credit facilities of $15.0 million, partially offset by the absence of the final repayment of Cleco Katrina/Rita storm recovery bonds of $11.1 million.

Contractual Obligations

Cleco, in the normal course of business activities, enters into a variety of contractual obligations. Some of these result in direct obligations that are reflected in Cleco’s Condensed Consolidated Balance Sheets while others are commitments, some firm and some based on uncertainties, that are not reflected in the Condensed Consolidated Financial Statements. For more information regarding Cleco’s Contractual Obligations, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Contractual Obligations” in the

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Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Off-Balance Sheet Commitments and Guarantees

Cleco Holdings and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit in order to facilitate their activities and the activities of Cleco Holdings’ subsidiaries and equity investees (affiliates). Cleco Holdings and Cleco Power have also agreed to contractual terms that require them to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees. For more information about off-balance sheet commitments and on-balance sheet guarantees, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Off-Balance Sheet Commitments and Guarantees.”

Cybersecurity

The operation of Cleco’s electrical systems relies on evolving operational and information technology systems and network infrastructures that are complex. The failure of Cleco or its vendors’ operational and information technology systems and networks due to a physical attack or cyber attack or other event could significantly disrupt operations; cause harm to the public or employees; result in outages or reduced generating output; result in damage to Cleco’s assets or operations, or those of third parties; result in damage to Cleco’s reputation; and subject Cleco to claims by customers or third parties, any of which could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants. Cleco continues to assess its cybersecurity tools and processes and has taken a variety of actions to monitor and address cyber-related risks. Cleco’s Chief Information and Supply Chain Officer leads Cleco’s cybersecurity team and oversees Cleco’s cybersecurity maturity plan. Each month, management provides cybersecurity updates to Cleco’s Asset Management Committee. On December 13, 2020, Cleco’s third party provider publicly confirmed a breach of its monitoring products in which a vulnerability was inserted and, if present and activated, could have potentially allowed an attacker to compromise the server on which the products run. Cleco found no impact to the confidentiality, integrity, or availability of its data or systems. The incident investigation has been closed by the third party provider. For more information on risks related to Cleco’s cybersecurity, see Part I, Item 1A, “Risk Factors — Operational Risks — Technology and Terrorism Threats” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Regulatory and Other Matters

Environmental Matters

Cleco is subject to extensive environmental regulation by federal, state, and local authorities and is required to comply with numerous environmental laws and regulations, and to obtain and comply with numerous governmental permits, in operating its facilities. In addition, existing environmental laws, regulations, and permits could be revised or reinterpreted; new laws and regulations could be adopted or become applicable to Cleco or its facilities; and future changes in environmental laws and regulations could occur, including potential regulatory and enforcement developments related to air

emissions, water and/or waste management. Cleco may incur significant additional costs to comply with these revisions, reinterpretations, and requirements. Cleco Power could then seek recovery of additional environmental compliance costs as riders through the LPSC’s EAC or FRP. If Cleco fails to comply with these revisions, reinterpretations, and requirements, it could be subject to civil or criminal liabilities and fines.

For a discussion of other Cleco environmental matters, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Environmental Audit” in this Quarterly Report on Form 10-Q and Part I, Item 1, “Business — Environmental Matters” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Regional Haze State Implementation Plan (SIP)

The Clean Air Act contains a regional haze program with the goal of returning Class I Federal areas of the nation to natural visibility by 2064. States are required to develop a SIP and revise it every ten years. A SIP must include requirements for the installation of Best Available Retrofit Technology (BART) for applicable electrical generating units in Louisiana. The EPA issued a final approval of the Louisiana SIP for the first planning phase in December 2017. Although the approval was appealed to the U.S. Court of Appeals for the Fifth Circuit by the Sierra Club and the National Parks Conservation Association, the court denied all the challenges to the EPA’s approval of the Louisiana Regional Haze SIP. Because the Louisiana SIP mandates use of existing controls and participation in the CSAPR as BART, Cleco does not believe the Louisiana SIP will have a material impact on the results of operations, financial condition, or cash flows of the Registrants. The second planning period for the regional haze program covers the period from 2018 through 2028 and requires states to adopt SIPs that make reasonable further progress toward achieving natural visibility conditions in Class I Federal areas. The LDEQ published a proposed SIP for the second planning period in April 2021 that is now receiving public comment and may be subject to revision upon further review by the LDEQ. The proposal does not call for new controls on any state sources but relies upon existing consent decrees and expected source retirements to achieve reasonable progress in reducing emissions and improving visibility in Class I Federal areas. The SIP for the second planning phase is due to be submitted to the EPA by July 31, 2021. Until the LDEQ determines what the reasonable progress requirements are for Cleco units and completes its update of the SIP and the EPA approves the SIP, Cleco is unable to predict if the second phase SIP will have a material impact on the results of operations, financial condition, or cash flows of the Registrants.

CPP and ACE

On January 19, 2021, the D.C. Circuit Court of Appeals ruled that the EPA’s repeal of the CPP and its 2019 promulgation of ACE were unlawful. Therefore, the court issued an order to vacate and remand the ACE rule to the EPA. On February 22, 2021, the court granted the EPA’s unopposed motion for a partial stay of the issuance of the mandate on vacating the CPP repeal ordering that it will withhold issuance of the mandate with respect to the vacatur of the CPP repeal until the EPA responds to the court’s remand by promulgating a new rule to regulate greenhouse gas emissions from existing

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electric generating units. This means that the CPP will not take effect during the EPA’s rulemaking process. In addition, on March 5, 2021, the court issued the partial mandate effectuating the court’s vacatur of the ACE rule which makes effective the court’s decision to vacate the ACE rule. At the end of April 2021, two parties filed petitions for a writ of certiorari asking the Supreme Court to review the decision by the D.C. Circuit Court of Appeals.

CSAPR

On September 13, 2019, the D.C. Circuit Court of Appeals partially remanded the CSAPR update rule to the EPA because the rule did not set a deadline by which upwind states must eliminate their significant contribution to downwind states’ National Ambient Air Quality Standards (NAAQS) nonattainment. In response to the remand of the rule, on October 30, 2020, the EPA published a proposed rule in the Federal Register, Revised CSAPR Update for the 2008 ozone NAAQS. On April 30, 2021, the EPA issued in the Federal Register the final rule. Cleco does not foresee the final regulation having a material impact on the results of operations, financial condition, or cash flow of the Registrants.

Solid Waste Disposal

On January 20, 2021, the President issued an executive order which directs federal agency heads to review regulations and other actions over the past four years to determine if they are inconsistent with the policies announced in the executive order. The administration also released a nonexhaustive list of agency actions to be reviewed, which includes the coal combustion by-products or residual rules promulgated in July 2018, August 2020, and November 2020. It is now indicated on the EPA coal ash rule website that the EPA completed review of the three coal combustion residuals rules in response to the executive order. The EPA determined that the most environmentally protective course is to implement these rules.

Retail Rates of Cleco Power

Base Rates

Effective July 1, 2021, Cleco Power’s annual retail earnings are subject to an FRP that was approved by the LPSC on June 16, 2021. For more information on the new FRP, see Note 11 — “Regulation and Rates — FRP.”

Fuel Rates

Generally, Cleco Power’s cost of fuel used for electric generation and the cost of purchased power are recovered through the LPSC-established FAC that enables Cleco Power to pass on to its customers substantially all such charges. Recovery of FAC costs is subject to periodic fuel audits by the LPSC. On May 11, 2021, Cleco Power received notice of an audit from the LPSC for fuel costs incurred during the time period required to restore services to Cleco Power’s customers during Winter Storms Uri and Viola. Management is unable to determine the outcome or timing of the audit. For more information on the FAC and the most recent fuel audits, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Fuel Audits.”

Environmental Rates

In July 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides Cleco Power an EAC to recover from customers certain costs of environmental compliance. These expenses are eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC. For more information on the EAC and the most recent environmental audit, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Environmental Audit.”

Energy Efficiency

In 2013, the LPSC issued a General Order adopting rules promoting energy efficiency programs. Cleco Power began participating in energy efficiency programs in November 2014. Cleco Power has recovered approximately $3.3 million annually for each of the program years through an approved rate tariff. In January 2018, Cleco began recovering an additional $3.3 million annually for estimated costs related to programs specific to political subdivisions.

On June 9, 2021, the LPSC initiated an audit on program years five and six to consider all program costs. Cleco Power has responded to the first set of data requests regarding the audit. Program years seven and thereafter are subject to audit. Management is unable to predict or give a reasonable estimate of the outcome of this or any future audits.

Generally, utility companies are allowed to recover from customers the accumulated decrease in revenues associated with the energy efficiency programs. On October 21, 2019, Cleco Power received notice of approval from the LPSC allowing recovery of the accumulated Lost Contribution to Fixed Cost revenues until base rates reset, which took effect on July 1, 2021.

Wholesale Rates

The rates Cleco, through Cleco Power and Cleco Cajun, charges its wholesale customers are subject to FERC’s triennial market power analysis. FERC requires a utility to pass a screening test as a condition for securing and/or retaining approval to sell electricity in wholesale markets at market-based rates. An updated market power analysis must be filed with FERC every three years or upon the occurrence of a change in status as defined by FERC regulation. Cleco filed its most recent triennial market power analysis on December 23, 2020.

Transmission Rates

Two complaints were filed with FERC seeking to reduce the ROE component of the transmission rates that MISO transmission owners, including Cleco, may collect under the MISO tariff. For more information about the ROE complaints, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — Transmission ROE.”

For information about the risks associated with Cleco’s participation in MISO, see Part I, Item 1A, “Risk Factors — Regulatory Risks — MISO” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

For information on transmission rates of Cleco, see Part II, Item 7, “Management’s Discussion and Analysis of Financial

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Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Transmission Rates” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Transmission, Distribution, and Generation Projects

Cleco Power’s significant ongoing projects include the Bayou Vista to Segura transmission project and the DSMART distribution project. For information on these projects, see “— Overview — Cleco Power.”

Market Restructuring

Wholesale Electric Markets

RTO

For information on Cleco Power’s operations within MISO and for information on regulatory aspects of wholesale electric markets affecting Cleco, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Market Restructuring — Wholesale Electric Markets” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

ERO

The Energy Policy Act of 2005 added Section 215 to the Federal Power Act, which provides for a uniform system of mandatory, enforceable reliability standards. In 2006, FERC named NERC as the ERO that will be required to develop and enforce the mandatory reliability standards.

A NERC Reliability Standards audit is conducted every three years for Cleco Power and Cleco Cajun. The next NERC Reliability Standards audits for Cleco Power and Cleco Cajun are scheduled to begin in 2022.

A NERC CIP audit is also conducted every three years for Cleco Power and Cleco Cajun. Cleco Power’s current NERC CIP audit was completed on August 14, 2020, and the final report was issued by SERC on November 5, 2020. Cleco Cajun’s most recent CIP audit occurred during June 2019, and the final report was issued by SERC on June 27, 2019. Management is unable to determine the timing of NERC’s approval of the final reports.

Management is also unable to predict the final financial outcome of the most recent CIP audits, any future audits, or whether any findings will have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants. For a discussion of risks associated with FERC’s regulation of Cleco Power’s transmission system, see Part I, Item 1A, “Risk Factors — Regulatory Risks — Reliability and CIP Standards Compliance” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Retail Electric Markets

For information on the regulatory aspects of retail electric markets affecting Cleco Power, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Market Restructuring — Retail Electric Markets” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Franchises

Cleco Power operates under nonexclusive franchise rights granted by governmental units, such as municipalities and parishes (counties), and enforced by state law. These franchises are for fixed terms, which vary from 10 years to more than 50 years. Historically, Cleco Power has been successful in the timely renewal of substantially all franchises as each neared the end of its term. Cleco Power’s next municipal franchise expires in April 2022.

For more information on franchises, see Part I, Item 1, “Business Regulatory Matters, Industry Developments, and Franchises — Franchises” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

Recent Authoritative Guidance

For a discussion of recent authoritative guidance, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 2 — Recent Authoritative Guidance.”

CRITICAL ACCOUNTING POLICIES

Cleco’s critical accounting policies include accounting policies that are important to Cleco’s financial condition and results of operations and that require management to make difficult, subjective, or complex judgments about future events, which could result in a material impact to the financial statements of Cleco. The preparation of financial statements contained in this report requires management to make estimates and assumptions. Estimates and assumptions about future events and their effects cannot be made with certainty. These estimates involve judgments regarding many factors that in and of themselves could materially affect the financial statements and disclosures. On an ongoing basis, these estimates and assumptions are evaluated and, if necessary, adjustments are made when warranted by new or updated information or by a change in circumstances or environment. Actual results may differ significantly from these estimates under different assumptions or conditions.

For more information on Cleco’s critical accounting policies, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Critical Accounting Policies” in the Registrant’s Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

CLECO POWER — NARRATIVE ANALYSIS OF RESULTS OF OPERATIONS

Cleco Power meets the conditions specified in General Instructions H(1)(a) and (b) to Form 10-Q and is, therefore, permitted to use the reduced disclosure format for wholly owned subsidiaries of reporting companies. Accordingly, Cleco Power has omitted from this report the information called for by Item 2 (Management’s Discussion and Analysis of Financial Condition and Results of Operations) and Item 3 (Quantitative and Qualitative Disclosures about Market Risk) of Part I of Form 10-Q and the following Part II items of Form 10-Q: Item 2 (Unregistered Sales of Equity Securities and Use of Proceeds) and Item 3 (Defaults upon Senior Securities).

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ITEM 3.      QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

RISK OVERVIEW

Cleco is exposed to counterparty credit risk, liquidity risk, interest rate risk, and commodity price risk. Cleco has implemented a governance framework, inclusive of risk policies and procedures to manage these and other risks.

Counterparty Credit Risk

When Cleco enters into commodity derivative or physical commodity transactions directly with market participants, Cleco may be exposed to counterparty credit risk. Cleco is exposed to counterparty credit risk when a counterparty fails to meet their financial obligations causing Cleco to incur replacement cost losses. Cleco may be required to provide credit support or pay liquidated damages with respect to any open trading contracts that Cleco has entered into or may enter into in the future. The amount of credit support that Cleco may be required to provide at any point in the future is dependent on credit terms and thresholds in master agreements, the notional value of the initial contract, changes in the market prices, changes in open contracts, and changes in the amounts counterparties owe to Cleco. Changes in any of these factors could cause the amount of requested credit support to increase or decrease.

Cleco monitors and manages its credit risk exposure through credit risk management policies and procedures that include:

•routine review of counterparty credit quality and credit exposure,

•entering into industry standard master agreements with specific terms and conditions for credit exposure and non-performance,

•measuring expected and potential future exposure regularly, and

•exchanging guarantees or forms of cash equivalent collateral for financial assurance.

For more information, see Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — General Considerations and Credit-Related Risks.”

Liquidity Risk

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. Future actions or inactions of the federal government, including a failure to increase the government debt limit, could increase the actual or perceived risk that the U.S. may not pay its obligations when due and may disrupt financial markets, including capital markets, potentially limiting availability and increasing costs of capital. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain and expand its businesses. After assessing the current operating performance, liquidity, and credit ratings of Cleco Holdings and Cleco Power, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. Cleco Holdings and Cleco Power pay fees and interest under their respective credit facilities based on the highest rating held. For more information, see Item 2, “Management’s

Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — General Considerations and Credit-Related Risks.”

Interest Rate Risk

Cleco monitors its mix of fixed- and variable-rate debt obligations in light of changing market conditions and from time to time may alter that mix, for example, refinancing balances outstanding under its variable-rate revolving credit facility with fixed-rate debt. Calculations of the changes in fair market value and interest expense of the debt securities are made over a one-year period.

Sensitivity to changes in interest rates for variable-rate obligations is computed by assuming a 1% change in the current interest rate applicable to such debt.

At June 30, 2021, Cleco Holdings had no short-term debt outstanding under its $175.0 million revolving credit facility. At June 30, 2021, the borrowing costs under Cleco Holdings’ revolving credit facility were equal to LIBOR plus 1.625% or ABR plus 0.625%, plus commitment fees of 0.275%.

At June 30, 2021, Cleco Holdings had a $266.0 million long-term variable rate bank term loan outstanding at an interest rate of LIBOR plus 1.625%, for an all-in interest rate of 1.725%. Each 1% increase in the interest rate applicable to Cleco Holdings’ long-term variable rate debt would result in a decrease in Cleco Holdings’ pretax earnings of $2.7 million on an annualized basis. The weighted average rate for all outstanding term loan debt at Cleco Holdings for the six months ended June 30, 2021, was 1.94%.

At June 30, 2021, Cleco Power had $160.0 million of short-term debt outstanding under its $300.0 million revolving credit facility at an all-in interest rate of 1.35%. At June 30, 2021, Cleco Power’s borrowing costs under its $300.0 million revolving credit facility were equal to LIBOR plus 1.25% or ABR plus 0.25%, plus commitment fees of 0.15%.

At June 30, 2021, Cleco Power had a $125.0 million long-term variable rate bank term loan outstanding, at an interest rate of LIBOR plus 1.25%, for an all-in interest rate of 1.35%. Each 1% increase in the interest rate applicable to Cleco Power’s short- and long-term variable rate debt would result in a decrease in Cleco Power’s pretax earnings of $2.9

million on an annualized basis. The weighted average rate for the outstanding term loan debt at Cleco Power for the six months ended June 30, 2021, was 1.37%.

Each 1% increase in the interest rate applicable to Cleco’s short- and long-term variable rate debt would result in a decrease in Cleco’s pretax earnings of $5.5 million on an annualized basis.

Cleco may enter into contracts to mitigate the volatility in interest rate risk. These contracts include, but are not limited to, interest rate swaps and treasury rate locks. For each reporting period presented, the Registrants did not enter into any contracts to mitigate the volatility in interest rate risk.

Commodity Price Risk

Cleco Power and Cleco Cajun’s financial performance can be impacted by changes in commodity prices that impact fuel costs, generation revenues, and customer supply costs and customer revenues. Cleco’s risk management policies and procedures authorize hedging commodity price risk with

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CLECO POWER	2021 2ND QUARTER FORM 10-Q

physical or financially settled derivative instruments within approved guidelines and limits of authority. Some of these transactions may qualify for the normal purchase, normal sale (NPNS) exception under derivative accounting guidance. Contracts that do not qualify for NPNS accounting treatment or are not elected for NPNS accounting treatment are marked-to-market and recorded on the balance sheet at their fair value.

Cleco Power and Cleco Cajun, each separately and individually, may be exposed to transmission congestion price risk as a result of physical transmission constraints present between MISO LMP nodes when serving customer load. Cleco Power and Cleco Cajun are awarded and/or purchase FTRs in auctions facilitated by MISO. FTRs are accounted for as derivatives not designated as hedging instruments for accounting purposes.

During the six months ended June 30, 2021, Cleco Cajun entered into gas-related derivative contracts including fixed price physical forwards and financially settled swap transactions. These are included in other commodity derivatives in the following tables.

The following tables present the fair values of derivative instruments and their respective line items as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021:

Cleco
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2021
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	8,662
Current	Energy risk management liabilities	(1,161)
Other commodity derivatives
Current	Energy risk management assets	30,063
Non-current	Other deferred charges	25,771
Commodity-related contracts, net		$	63,335

Cleco Power
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2021
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	6,867
Current	Energy risk management liabilities	(877)
Commodity-related contracts, net		$	5,990

Cleco monitors the Value at Risk (VaR) of its other commodity derivative contracts requiring derivative accounting treatment. VaR is defined as the minimum expected loss over a given holding period at a given confidence level based on observable market price volatilities. Cleco uses a parametric variance-covariance model methodology to estimate VaR. VaR is calculated using historical volatilities within a 5-day holding period at a 95% confidence interval. Given Cleco’s reliance on historical data, VaR is effective in estimating risk exposures in markets in which there are no sudden fundamental changes or abnormal shifts in market conditions. An inherent limitation of VaR is that past changes in market risk factors, even when weighted toward more recent observations, may not produce accurate predictions of future market risk. VaR should be evaluated in light of this and the methodology’s other limitations.

The following table presents the VaR of other commodity derivative contracts based on these assumptions:

			FOR THE THREE MONTHS ENDED JUNE 30, 2021						FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	AT JUNE 30, 2021		HIGH		LOW		AVERAGE		HIGH		LOW		AVERAGE
Cleco	$	8,345	$	11,589	$	7,382	$	9,005	$	12,234	$	7,199	$	9,032

For more information on the accounting treatment and fair value of FTRs and other commodity derivatives, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial

Statements — Note 6 — Fair Value Accounting — Commodity Contracts.

ITEM 4.     CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of Cleco Holdings and Cleco Power (individually, “Registrant” and collectively, the “Registrants”) management, including the CEO and CFO, the Registrants have evaluated the effectiveness of their disclosure controls and procedures as of June 30, 2021. Based on the evaluations, the CEO and CFO have concluded that the Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), is recorded, processed, summarized, and reported within the time periods specified in SEC rules and forms; and

that the Registrants’ disclosure controls and procedures are also effective in ensuring that such information is accumulated and communicated to the Registrants’ management, including the CEO and CFO, as appropriate, to allow timely decisions regarding required disclosure.

Changes in Internal Control over Financial Reporting

There have been no changes in the Registrants’ internal control over financial reporting that occurred during the quarter ended June 30, 2021, that have materially affected, or are reasonably likely to materially affect, the Registrants’ internal control over financial reporting.

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PART II — OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

CLECO

For information on legal proceedings affecting Cleco, see Part I, Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation.”

CLECO POWER

For information on legal proceedings affecting Cleco Power, see Part I, Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation.”

ITEM 1A.      RISK FACTORS

There have been no material changes from the risk factors disclosed in Part I, Item 1A, “Risk Factors” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020. For risks that could affect actual results and cause results to differ materially from those

expressed in any forward-looking statements made by, or on behalf of, the Registrants, see the risk factors disclosed under Part I, Item 1A, “Risk Factors” of the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

ITEM 6.  EXHIBITS
CLECO
10.1	Credit Agreement, dated as of May 21, 2021, by and among Cleco Corporate Holdings LLC, the lenders party thereto and Regions Bank, as administrative agent (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed May 26, 2021)
10.2	Term Loan Agreement, dated as of May 21, 2021, by and among Cleco Corporate Holdings LLC, the lenders party thereto and Regions Bank, as administrative agent (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K filed May 26, 2021)
10.3	Cleco Corporate Holdings LLC Executive Severance Plan, effective May 21, 2021
31.1	CEO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
31.2	CFO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
32.1	CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
32.2	CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
101.INS	Inline 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	Inline XBRL Taxonomy Extension Schema
101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase
101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase
101.LAB	Inline XBRL Taxonomy Extension Label Linkbase
101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase
104	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)
CLECO POWER
10.4	Credit Agreement, dated as of May 21, 2021, by and among Cleco Power LLC, the lenders party thereto and Regions Bank, as administrative agent (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed May 26, 2021)
10.5	Term Loan Agreement, dated as of May 21, 2021, by and among Cleco Power LLC, the lenders party thereto and Regions Bank, as administrative agent (incorporated by reference to Exhibit 10.2 to the Current Report on Form 8-K filed May 26, 2021)
31.3	CEO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
31.4	CFO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
32.3	CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
32.4	CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
101.INS	Inline 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	Inline XBRL Taxonomy Extension Schema
101.CAL	Inline XBRL Taxonomy Extension Calculation Linkbase
101.DEF	Inline XBRL Taxonomy Extension Definition Linkbase
101.LAB	Inline XBRL Taxonomy Extension Label Linkbase
101.PRE	Inline XBRL Taxonomy Extension Presentation Linkbase
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.

CLECO CORPORATE HOLDINGS LLC
(Registrant)
By:	/s/ F. Tonita Laprarie
	F. Tonita Laprarie
	Controller and Chief Accounting Officer

Date: August 11, 2021

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.

CLECO POWER LLC
(Registrant)
By:	/s/ F. Tonita Laprarie
	F. Tonita Laprarie
	Controller and Chief Accounting Officer

Date: August 11, 2021

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EX-10.3

Executive Severance Plan

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Exhibit 10.3

CLECO CORPORATE HOLDINGS LLC

EXECUTIVE SEVERANCE PLAN

    THIS AMENDED AND RESTATED EXECUTIVE SEVERANCE PLAN (the "Plan") is adopted by Cleco Corporate Holdings LLC (the "Company") effective as set forth below.

1.    Purpose:

    This Plan is intended to be a welfare benefit plan within the meaning of the Employee Retirement Income Security Act of 1974, as amended ("ERISA"), which benefits a select group of key management employees, subject to the terms and conditions set forth herein.

2.    Definitions:

2.1    “Affected Entity” means the Company, Cleco Power LLC, or Cleco Cajun LLC.

2.2    "Affiliate" means a subsidiary or affiliate of the Company, at least 80% of the equity securities of which are owned directly or indirectly by the Company.

2.3    "Average Bonus" means the average of a Covered Executive's annual bonus payable under the Company's Annual Incentive Plan, or any successor thereto, during the three whole fiscal years immediately preceding such executive's Separation Date; provided that if a Covered Executive has not been employed by the Company during the three whole fiscal years preceding his or her Separation Date, such average shall be determined with respect to amounts payable during his or her actual period of eligibility.

2.4    "Base Compensation" means a Covered Executive's periodic regular rate of pay, determined without regard to any bonus, incentive, equity compensation, fringe benefit or similar amount. "Annualized Base Compensation" means the annualized rate of a Covered Executive's Base Compensation in effect immediately prior to the commencement of a Change in Control Period.

2.5    "Board" or "Board of Managers" means the Board of Managers of the Company.

2.6    "Change in Control." The Company’s Board of Managers determines whether a "Change in Control" has occurred using the following guidelines:

a.    A Triggering Acquiror of an Affected Entity is or becomes the "beneficial owner" (as determined in Rule 13d-3 promulgated under the Exchange Act) of 80% or more of the combined voting power of the outstanding securities of such Affected Entity;

b.    An Affected Entity is party to a merger or consolidation with another entity and, as a result of such transaction, 80% or more of the combined voting power of outstanding securities of the Affected Entity or its successor in the merger (or a direct or indirect parent company of the Affected Entity or its successor in the merger) is owned in the aggregate by persons who were not "beneficial owners" (as determined in Rule 13d-3 promulgated under the Exchange Act) of securities of such Affected Entity immediately before such transaction;

c.    The owners of an Affected Entity approve a plan of dissolution or liquidation; or

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Executive Severance Plan

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d.    All or substantially all of the assets or the issued and outstanding membership interests of an Affected Entity are sold, leased or otherwise disposed of in one or a series of related transactions to a person, other than another Affected Entity or an Affiliate.

2.7    "Change in Control Period" means the 60-day period preceding and the 24-month period following the consummation of a Change in Control.

2.8    "Code" means the Internal Revenue Code of 1986, as amended, including any successor thereto and any regulation or other guidance promulgated thereunder.

2.9    "Committee” means the Board of Managers of the Company as constituted from time to time, or any designee thereof.

2.10    "Constructive Termination" means: (a) a material reduction, other than a reduction in pay uniformly applicable to all officers of the Company, in the amount of a Covered Executive's Base Compensation; and (b) a contemporaneous, material diminution in a Covered Executive's authority, duties or responsibilities. No event or condition shall constitute a Constructive Termination hereunder unless: (i) a Covered Executive provides to the Committee written notice of his or her objection to such event not later than 60 days after such executive first learns, or should have learned, of such event; (ii) such event is not corrected by the Company promptly after receipt of such notice, but in no event more than 30 days after receipt thereof; and (iii) such executive Separates From Service not more than 15 days following the expiration of the 30-day period described in clause (ii) hereof.

2.11    "Covered Executive" means a common law employee of the Employer who is eligible to receive benefits in accordance with the provisions of this Plan (a) by virtue of holding the title of "director", or above as reflected in Exhibits A and B, or (b) pursuant to the terms of an employment or similar agreement.

2.12    "Employer" means the Company, Cleco Power LLC, Cleco Support Group LLC,Cleco Cajun LLC, and any other Affiliate.

2.13    "Exchange Act" means the Securities Exchange Act of 1934, as amended, including any rule, regulation or interpretation promulgated thereunder.

2.14    "Good Reason" means that: (a) a Covered Executive's Base Compensation in effect immediately before the commencement of a Change in Control Period is materially reduced, or there is a material reduction or termination of such executive's rights to any employee benefit in effect immediately prior tosuch period; (b) a Covered Executive's authority, duties or responsibilities are materially reduced from those in effect immediately before the commencement of a Change in Control Period (it being understood that in no event shall a Covered Executive's authority, duties or responsibilities be deemed to be reduced as a consequence of or related to the Company ceasing to be a publicly listed company); (c) a Covered Executive is required to be away from his or her office in the course of discharging his or her duties and responsibilities significantly more than was required before the commencement of a Change in Control Period; or (d) a Covered Executive is required to transfer to an office or business location that is more than 60 miles from the primary location to which he or she was assigned prior to the commencement of a Change in Control Period. No event or condition shall constitute Good Reason hereunder unless: (i) a

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Covered Executive provides to the Committee written notice of his or her objection to such event not later than 60 days after such executive first learns, or should have learned, of such event; (ii) such event is not corrected by the Company promptly after receipt of such notice, but in no event more than 30 days after receipt thereof; and (iii) such executive Separates From Service not more than 15 days following the expiration of the 30-day period described in clause (ii) hereof.

2.15    "Participant” means a Covered Executive who has satisfied the conditions of Section 3.2 hereof and is otherwise eligible to receive benefits hereunder.”

2.16    "Severance Benefits" means Basic Severance and Change in Control Severance; "Basic Severance" means payments and benefits on account of a Participant's Separation from Service, other than during a Change in Control Period; "Change in Control Severance" means payments and benefits on account of a Participant's Separation From Service during a Change in Control Period.

2.17    “Triggering Acquiror” of an Affected Entity means any "person" (as such term is used in Sections 13(d) and 14(d) of the Exchange Act), other than the Company or an Affiliate or any "person" who on the effective date of this Plan is a manager, officer, or is the "beneficial owner" (as determined in Rule 13d-3 promulgated under the Exchange Act) of 20% or more of the combined voting power of outstanding securities of such Affected Entity or of an employee stock ownership plan (within the meaning of Code Section 4975(e)(7)) sponsored by such Affected Entity.

2.18    "Years of Employment" or "YOE" means a Participant's period of consecutive service with the Employer, determined as of his or her Separation Date, measured in 12-month increments; a partial period of not less than six whole months shall be treated as a full Year of Employment; a partial period of less than six whole months shall be disregarded. If a Participant terminates his or her employment with the Employer and is later rehired, Years of Employment shall be measured from his or her reemployment date.

2.19    Further Definitions. The terms "Cause,""Disability,""Retirement," "Separation Date" and "Separation From Service" shall have the meanings ascribed to them in the Company's 2017 Long-Term Incentive Compensation Plan, as the same may be amended, modified, restated or replaced, from time to time (the "LTIP").

3.    Eligibility for Severance Benefits:

3.1    Qualifying Separation. A Covered Executive may be eligible to receive Basic Severance or Change in Control Severance, as the case may be, provided his or her Separation From Service constitutes a Qualifying Separation. For this purpose, the term "Qualifying Separation" shall mean a Separation From Service that:

a.    Is involuntary by the Covered Executive, other than on account of Cause, or is initiated by a Covered Executive on account of Good Reason or Constructive Termination, as the case may be.

    b.    With respect to Basic Severance, further: (1) that a Covered Executive's Separation Date does not occur during a Change in Control Period; (ii) that such executive's Separation From Service was not initiated by the Company on account of poor performance, whether or not constituting Cause; and (iii) if such Qualifying Separation is in connection with a merger, acquisition, sale, transfer, reorganization or restructuring of the Company or any Affiliate or business unit or division thereof, other than a Change in Control, that such executive is not

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offered another position with the Employer, the acquiring entity or their successors that provides base salary and bonus opportunity substantially equal in the aggregate to his or her then current Base Compensation and bonus opportunity.

    c.    With respect to Change in Control Severance, further that a Covered Executive's Qualifying Separation occurs during a Change in Control Period.

3.2    Waiver, Release and Covenants. Upon a Covered Executive's Qualifying Separation, the Committee, or its designee, shall provide to such executive written notice of his or her eligibility for Severance Benefits hereunder; provided, however, that as a condition of receiving such benefits, he or she shall be required to execute and timely deliver to the Company such agreement or agreements as the Company, in its sole discretion, shall deem necessary or appropriate to protect its business and economic value, including the business and economic value of its Affiliates, such agreement or agreements to provide for any one or more of the following: a waiver and release in favor of the Company and its Affiliates; covenants protecting confidential information; covenants prohibiting competition; covenants prohibiting the solicitation of customers and employees; and prohibitions on disparagement by the Executive and the Company and to be substantially in the form attached hereto as Exhibit 1, "Basic Waiver, Release and Covenants Agreement," as the same may be modified in the discretion of the Committee from time to time.

4.    Terms and Conditions Applicable to Severance Benefits:

4.1    Benefits. Subject to the terms and conditions of payment otherwise set forth herein, Basic Severance shall consist of those cash payments set forth on Exhibit A hereto, the terms of which are incorporated herein by this reference; Change in Control Severance shall consist of those cash payments and benefits set forth on Exhibit B hereto, the terms of which are incorporated herein by reference.

4.2    Cash Payments, Except asprovided in Section 4.5 hereof, any Base Compensation Cash Payment, Cash Payment in Lieu of Outplacement, and/or Change in Control Cash Payment, each as described in Exhibit A or B hereto, shall be aggregated and paid in the form of a single-sum on or before the 60th day following the Participant's Separation Date, provided that such Participant's Release has then become irrevocable.

4.3    Medical Benefits. Medical Benefits hereunder may consist of:

    a.    Access to continuation coverage under the Company's group medical plan, which coverage (i) shall be contingent upon each Participant's timely election to continue coverage under such plan within the meaning of Code Section 4980B, and (ii) shall offset any period of continuation coverage otherwise available under applicable law; and/or

    b.    Cash payments in an amount equal to the full cost of the same type and level of continuation coverage under the Company's group medical plan as elected by such Participant and/or his or her spouse or dependents under Code Section 4980B. Cash payments hereunder shall be made monthly during the period specified in Exhibit A or B hereto, as the case may be, 30 days in arrears.

Access to coverage and/or cash payments hereunder shall cease or be reduced, as the case may be, upon the earlier of the period specified in Exhibit A or B hereto or, if earlier, the date on which such Participant or his or her spouse or dependent becomes eligible for coverage under another employer's group medical plan.

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4.4    Home Purchase and Relocation. Subject to the provisions of Exhibit B hereto:

    a.    The Company shall purchase the principal residence occupied by a Participant as of his or her Separation Date (such Participant's "Principal Residence"), provided such Principal Residence is located within 60 miles of the Participant's primary work location, for an amount equal to the greater of (i) the fair market value of such residence as determined by the Company's third party relocation service, or (ii) the purchase price of such residence and the documented cost of any capital improvements made by the Participant, but not more than 120% of such purchase price.

    b.    The Company shall further pay or reimburse a Participant for the cost of relocation, including the relocation of his or her immediate family and their household goods and other personal property, in accordance with the Company's usual relocation practice, to any location in the continental United States.

    Notwithstanding the foregoing, the Company shall not be obligated hereunder, unless: (a) a Participant actually relocates to a new principal residence that is more than 100 miles from his or her Principal Residence, and (b) such Participant submits his or her written request to the Company for the purchase of such Principal Residence hereunder not later than 12 months after his or her Separation Date. In any event, payment hereunder shall be made not later than December 31 of the calendar year following the year in which a Participant's Separation Date occurs.

4.5    Code Section 409A Compliance. If a Participant is a "specified employee" within the meaning of Code Section 409A as of his or her Separation Date and any amount or benefit payable or due hereunder is deemed to constitute "deferred compensation" that is subject to the payment restrictions set forth in Code Section 409A, the Company shall delay the payment of all or the affected portion of any such amount or benefit until the first business day of the seventh month following such Participant's Separation Date. Payment shall be made as soon as practicable thereafter, but without liability for interest or loss of investment opportunity. Status as a "specified employee" shall be determined by the Committee in accordance with Code Section 409A and regulations and guidance issued with respect thereto. For this purpose, each payment or benefit hereunder shall be designated as a separate payment or benefit under the short-term deferral provisions, the exemption for involuntary termination payments, the exemption for in-kind benefits, and the exemption for medical expense reimbursements.

    Any payment or benefit hereunder that is deemed "deferred compensation" within the meaning of Code Section 409A and that could be due in one of two years shall be paid in the second such year.

4.6    Excise Tax Limitation. If any payment or benefit made or provided to a Participant by the Company or an Affiliate, is subject to the excise tax imposed under Code Section 4999 or similar tax or penalty, then such payment or benefit, including Severance Benefits hereunder; shall be reduced to the minimum extent necessary to avoid the imposition of such tax by reducing cash payments hereunder. The amount of any such reduction shall be determined by a nationally recognized public accounting firm retained by the Company, as soon as practicable following a Participant's Separation Date. All fees and expenses of such accounting firm shall be borne by the Company. The Company and any affected Participant shall promptly furnish to such accounting firm such information as may be reasonably required to calculate any reduction hereunder. Such accounting firm shall provide a written determination of such reduction, together with detailed supporting calculations to the Company and the Participant, which shall be binding upon such parties.

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5.    Other Benefits:

5.1    Annual Incentive Plan. In addition to any Severance Benefits hereunder, each Participant shall receive under the Company's Short-Term Incentive Plan, or any successor thereto, an annual incentive for the Company's fiscal year in which his or her Separation Date occurs, which:

    a.    With respect to Basic Severance, shall be (i) determined in accordance with the terms of such plan, (ii) prorated to reflect his or her period of service during such year, and (iii) paid at the time such incentives are customarily paid.

    b.    With respect to Change in Control Severance, shall be (i) determined as such Participant's target incentive for such year, (ii) prorated to reflect his or her period of service during such year, and (iii) paid at the time or times determined in accordance with Section 4.2 hereof.

5.2    Long-Term Incentive Compensation Plan. Each Participant shall receive, in addition to any Severance Benefits hereunder, all rights and benefits to which he or she may be entitled under the LTIP, including any predecessor thereto; the terms and conditions of such plan and any individual grant or award thereunder shall govern the rights and benefits afforded to each Participant therein.

5.3    Business Expenses. The Company shall reimburse a Covered Executive for any reasonable and necessary business expenses incurred but not yet reimbursed as of his or her Separation Date, provided that the expenses are otherwise reimbursable under the Company's standard reimbursement policy and that any request for reimbursement is made and documented in accordance with the Company's standard practices.

5.4    Other Plans, Policies and Arrangements. Except as expressly provided herein, nothing contained in this Plan is intended to impair or diminish any benefit or right accrued and vested as of a Covered Executive's Separation Date under a separate employee benefit plan or program maintained by the Employer, which shall be administered and paid in accordance with its terms; provided, however that as a condition of the receipt of a benefit hereunder, a Participant shall be deemed to have waived and forfeited any right to receive termination, separation or severance benefits, whether payable under the terms of an employment or similar arrangement with the Company or an Affiliate or under a separate severance pay plan, policy or program maintained by the Company or an Affiliate.

6.    Administration and Claims:

6.1    Administration. The Committee shall administer this Plan, in its discretion. Among other things, it shall determine the position or title of each Participant as of his or her Separation Date, whether the conditions applicable to the receipt of any Severance Benefits hereunder have been satisfied, and the amount or form of Severance Benefits payable hereunder. The Committee may adopt rules and procedures and has the discretionary authority to determine all questions of eligibility for participation and for benefits and it has the discretionary authority to interpret the Plan and any form or document related to the Plan, including the resolution of uncertainty created by any conflict, ambiguity or omission contained in the Plan and/or its related forms and documents. The Committee may delegate to the appropriate officers and employees of the Company one or more of its duties and obligations hereunder.

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6.2    Claims. The Committee or its designee shall furnish each Covered Executive with any necessary documents to claim Severance Benefits hereunder at the time of his or her Separation From Service, or as soon as practicable thereafter.

    If a Covered Executive believes he or she is eligible to receive Severance Benefits, or that the amount of any such benefit has not been correctly determined, such executive may file a written claim with the Committee through the Company's Human Resources Department. Such claim shall identify the amount in controversy, include a description of the circumstances and provisions of the Plan supporting the claim, and include any documents or other evidence that supports payment of the disputed amount.

    The Committee shall respond, in writing, within 90 days following the receipt of such claim. If the claim is denied, in whole or in part, the response shall include the reasons why the claim is denied and identify the Plan provisions and employment records upon which the denial is based. A denial hereunder can be appealed by providing written notice to the Company's Human Resources Department not later than 60 days after the denial is received. A Covered Executive may request copies of any documents in the possession of the Employer relevant to the determination of his or her Severance Benefits, such as salary history, promotion records and a copy of the Plan. The Committee shall provide to the Covered Executive written notice of its disposition not later than 60 days after the appeal is received.

    If a Covered Executive fails to file a claim within 12 months after his or her Separation Date, his or her Severance Benefits paid hereunder; if any, shall be deemed final and correct. If a Covered Executive fails to appeal a claim within the time provided herein, the initial determination of the Committee shall be deemed final and binding on all persons claiming an interest or right in such benefit.

    No arbitration or other legal action to recover benefits or with respect to any other matter related to this Plan may be commenced before the claimant has timely exhausted the claim and appeal procedures described above. In no event may any such action be brought more than 6 months after the date of decision on an appeal.

7.    General Provisions:

7.1    Spendthrift Provision. Severance Benefits hereunder are not subject in any manner to anticipation, alienation, sale, transfer, assignment, pledge, encumbrance or charge. Any attempt to anticipate, alienate, sell, transfer, assign, pledge, encumber or charge such benefit will be void and given no effect. Any benefit payable under the terms of the Plan shall not be subject to attachment or legal process, and any such action shall not be recognized by the Employer.

7.2    Employment Rights. Participation in the Plan is not an employment agreement; nothing contained herein is intended to provide a Covered Executive the right to be retained in the employ of the Employer, absent a written agreement to the contrary.

7.3    Amendment or Termination. Except as provided herein, the Company has no obligation to maintain the Plan for any particular length of time; the Committee possesses the right, at any time, to amend or terminate this Plan, in whole or in part, by providing 30 days prior written notice to each Covered Executive hereunder. Notwithstanding the foregoing: (a) no amendment or termination shall impair any Severance Benefits due with respect to a Qualifying Separation that occurs before the adoption or effective date of any such amendment or termination; and (b) no termination or other amendment that materially adversely affects the rights or benefits of any Covered Executive hereunder shall be made or effective during the Change in Control Period, without the prior written consent of such executive.

Page 7 of 11

Executive Severance Plan

Page 8 of 11

Nothing contained herein shall be deemed to amend any plan, policy or program maintained by the Employer, or to prohibit the amendment, modification or termination of any plan, policy or program maintained by the Employer, including but not limited to the group medical plan, which shall be at the discretion of the Employer in accordance with the provisions of any such plan.

7.4    Debts to Employer; Coordination with WARN. Benefits otherwise payable under the Plan will be reduced by any amounts that the Covered Executive is obligated to repay or that the Covered Executive owes to the Employer for any reason, including for Employer equipment or other property. Severance Benefits payable hereunder shall be reduced by any amount required to be paid under the Worker Adjustment and Retraining Notification Act.

7.5    Successors; Binding Plan. This Plan is binding upon the Company and any successor to the Company, whether by purchase, merger, consolidation or otherwise. This Plan shall inure to the benefit of each Covered Executive, including his or her personal or legal representatives, and executors or heirs. If a Participant dies while Severance Benefits remain payable hereunder, the remaining amount shall be paid to his or her surviving spouse or estate.

7.6    Governing Law. The Plan is governed by federal law to the extent applicable, and to the extent not applicable, by the internal laws of the State of Louisiana, without regard to its principles concerning conflicts of law.

7.7    General Assets. Benefits payable from the Plan are solely from the general assets of the Employer. The Employer has not established a trust or earmarked any asset to pay benefits, and it has not acquired any form of insurance to fund any benefit hereunder.

7.8    Taxes. As a condition of any payment hereunder, the Company shall withhold and deduct from any payments made under this Plan all federal, state or local taxes required by applicable law to be withheld.

7.9    Attorneys' Fees. In the event any dispute in connection with this Plan arises with respect to the payment of Severance Benefits hereunder, all costs, fees and expenses, including attorneys' fees, of any legal action in connection with such matters shall be borne by the Company, provided that a Covered Executive prevails on at least one material issue.

7.10    Arbitration. As a condition of the receipt of Severance Benefits under the Plan, any dispute or controversy that arises hereunder and after the Plan's claims procedures are timely exhausted, shall be resolved by arbitration. Any arbitration proceeding shall be conducted in accordance with the employment rules of JAMS. Any dispute or claim shall be presented to a single arbitrator selected by the mutual agreement of the parties (or the arbitrator will be selected in accordance with the rules of JAMS). All determinations of the arbitrator will be final and binding. Subject to Section 7.9, each party to the arbitration proceeding will bear its own costs in connection with the proceedings, except that the costs and expenses of the arbitrator will be divided evenly between the parties. As part of the consideration for participation in this Plan, the Covered Executive agrees that the venue for any arbitration proceeding will be in Pineville, Louisiana and that the state and federal courts in Alexandria, Louisiana, shall have exclusion jurisdiction of any claim to which the arbitration provision in this Plan does not apply (including a judicial proceeding to enforce the Plan's arbitration provision), and the Covered Executive consents to the personal jurisdiction of any such court.

Page 8 of 11

Executive Severance Plan

Page 9 of 11

THIS EXECUTIVE SEVERANCE PLAN was approved by the Board of Managers of Cleco Corporate Holdings LLC on May 21, 2021, to be effective as of such date.

Cleco Corporate Holdings LLC

By: /s/ William Fontenot

William Fontenot

President and Chief Executive Officer

Date: May 21, 2021

Page 9 of 11

Executive Severance Plan

Page 10 of 11

EXHIBIT A

BASIC SEVERANCE BENEFITS

BASIC SEVERANCE BENEFITS
Title	Base Compensation Cash Payment	Cash Payment in Lieu of Outplacement	Medical Benefits/Payments
Director	Minimum Benefit: 16 weeks of Base Compensation	$10,000	Cash payments for a maximum period equal to the number of whole months of Base Compensation Cash Payment
	Additional two weeks for each YOE
	Maximum Benefit: 52 weeks of Base Compensation
Vice President	Minimum Benefit: 32 weeks of Base Compensation	$20,000	Cash payments for a maximum period equal to the number of whole months of Base Compensation Cash Payment
	Additional one month for each YOE
	Maximum Benefit: 52 weeks of Base Compensation
Executive Management Team	52 weeks of Base Compensation	$25,000	Cash payments for a maximum period of 18 months
President & CEO	52 weeks of Base Compensation	$50,000	Cash payments for a maximum period of 18 months

Page 10 of 11

Executive Severance Plan

Page 11 of 11

EXHIBIT B

CHANGE IN CONTROL SEVERANCE BENEFITS

CHANGE IN CONTROL SEVERANCE BENEFITS
Title	Change in Control Cash Payment	Home Purchase/ Relocation	Medical Benefits/Payments
Director	Same as Basic Severance Benefits (Exhibit A)	NA	Cash payments for a maximum period equal to the number of whole months of Base Compensation Cash Payment
Vice President	2 X the sum of Annualized Base Compensation and Average Bonus	Available	Cash payments and coverage for a maximum period of 24 months
Executive Management Team or above	2 X the sum of Annualized Base Compensation and Average Bonus	Available	Cash payments and coverage for a maximum period of 24 months

Page 11 of 11

EXHIBIT 1

CLECO CORPORATE HOLDINGS LLC EXECUTIVE SEVERANCE PLAN

BASIC WAIVER, RELEASE AND COVENANTS AGREEMENT

Name of Executive:

Date of Delivery:

Type and Duration of Severance

Basic Severance     Change in Control Severance

Duration _________ weeks

THIS BASIC WAIVER, RELEASE AND COVENANTS AGREEMENT (the "Agreement") is made and delivered by the executive named above ("Executive") in consideration and as a condition of the receipt of payments as a Covered Executive under and a Participant in the Executive Severance Plan maintained by Cleco Corporate Holdings LLC (the "Company"), as the same has been amended from time to time (the "Plan"), the adequacy of which consideration is hereby acknowledged.

1.    WAIVER AND RELEASE:

1.1    Claims Released. Executive, on his or her own behalf and on behalf of Executive's heirs, successors and assigns, hereby releases and discharges the Company and its Affiliates, and their respective past, present, or future parents, subsidiaries and affiliates, regardless of the form of entity in which maintained, shareholders, officers, directors, managers, members, partners, owners, agents, trustees, administrators, insurers, attorneys, employees, and employee benefit plans or funds and their fiduciaries, including any predecessors, successors and/or assigns thereto (collectively, the "Protected Parties") from any claims, demands, causes of action and liabilities of any kind (including attorneys' fees and costs), whether based in law or equity, whether contractual or based in common or statutory law, including federal, state, and local laws, whether known or unknown, which Executive had, may now have, or hereafter may have, against the Protected Parties based upon facts occurring up to and including the date of the execution of this Agreement, other than the claims retained as provided in Section 1.2 hereof. Without limiting the generality of the foregoing, Executive hereby specifically releases and discharges the Protected Parties from:

    a.    Any claims relating to Executive's employment by the Protected Parties, including the termination thereof, the terms and conditions of such employment, employee benefits and compensation related to such employment, and/or any of the events relating, directly or indirectly, to or surrounding Executive's termination, including but not limited to claims for discriminatory, wrongful or retaliatory discharge, breach of contract, tort, defamation, slander, and emotional distress, and

    b.    Any claims of discrimination, harassment, whistle blowing or retaliation in connection with Executive's employment, and the termination thereof, whether arising under federal, state or local law, including, without limitation, all claims arising under Title VII of the Civil Rights Act of 1964, as amended, the Americans with Disabilities Act, the Civil Rights Act of 1991, the Reconstruction Era Civil Rights Act of 1866, 42 USC §§ 1981-86, as amended, the Rehabilitation Act of 1973, the Equal Pay Act, the Family and Medical Leave Act, the Employee Retirement Income Security Act of 1974, as amended, the Sarbanes-Oxley Act of 2002, and, to the extent applicable to Executive, the Age Discrimination in Employment Act of 1967, as amended, and the Older Workers' Benefit Protection Act of 1990, as amended.

Page 1 of 6

1.2    Claims Retained. Notwithstanding the generality of the foregoing Section 1.1, Executive does not waive or release any right or claim (a) arising after the date on which Executive executes this Agreement, (b) ordinary claims for benefits accrued and vested or due as of his or her Separation Date under any benefit plan subject to the Employee Retirement Income Security Act of 1974, as amended, or other benefit plan or arrangement sponsored and maintained by the Protected Parties; (c) severance amounts payable to him or her under the terms of the Plan, as described above, including the Cash Payment in Lieu of Outplacements and Medical Benefits/Payments, each as more fully described in the Plan, (d) any claim for compensation due under applicable law that cannot be waived as a matter of public policy, (e) any right to indemnification that Executive may possess as a director, manager, officer or employee of any of the Protected Parties to the fullest extent provided under the indemnification and insurance arrangements or governing documents of such parties or applicable law, and (f) any other right or benefit required by law to be provided.

1.3    Charges. Nothing contained herein shall be deemed to prevent Executive from filing a charge or complaint, including a challenge to the validity of Section 1.1 of this Agreement, with the Equal Employment Opportunity Commission ("EEOC") or from participating in any investigation or proceeding conducted by the EEOC, provided that Executive understands and agrees that he or she shall not be entitled to participate in or receive any damages or other type or form of award relating to any event that occurred prior to his or her execution of this Agreement as a consequence thereof.

2.    EXECUTIVE'S COVENANTS:

2.1    Confidential Information. Executive recognizes and acknowledges that he or she has and will continue to possess confidential, proprietary, non-public information concerning the Protected Parties, whether or not deemed a "trade secret" under applicable law, which may include, without limitation (a) books and records relating to operations, finance, accounting, personnel and management, (b) cost, price, rate and volume data, future price, rate and trading plans, and test data; (c) product and plant design and development; (d) records, computer software, customer lists, information obtained on competitors, and sales tactics, and (e) various other non-public trade or business information, including strategic business opportunities, marketing, business diversification and expansion plans, acquisitions, dispositions, methods and processes, financial data and the like (collectively, the "Confidential Information"). Executive agrees that he or she will not, at any time, make any independent use or disclosure of the Confidential Information, provided that nothing contained herein shall prohibit the use and disclosure of Confidential Information. (x) with the prior written consent of the Company, (y) to the extent required by law or by legal process, provided that Executive shall furnish to the Company not less than five business days prior to such disclosure, or such shorter period as may be necessitated by facts and circumstances, written notice of such law or process, including a copy of all relevant documents, and shall cooperate with the Company to object to such disclosure or to place such disclosure under seal, or (z) if and to the extent such information shall have become public information, other than on account of Executive's breach of this covenant.

2.2    Non-Solicitation of Employees. Executive agrees that during the Restricted Period (as defined below), he or she shall not, directly or indirectly, whether for his or her own benefit or on behalf of another, or to the Company's detriment, hire or offer to hire, or cause any person to hire or offer to hire, any officer, employee or manager of the Protected Parties, or persuade, or attempt to persuade, any such officer, employee or manager to discontinue any relationship with the Protected Parties, provided that general advertisements and/or contact by third-party recruiters that is not initiated, directly or indirectly, by Executive shall not be deemed a breach hereof. For purposes of this Section 2.2, the term "officer, employee or manager of the Protected Parties" shall mean and be deemed to refer to individuals who are employed by the Protected Parties and individuals who ceased employment with the Protected Parties during the six-month period preceding the occurrence of a solicitation prohibited hereunder.

Page 2 of 6

2.3    Business Reputation. Executive agrees that he or she shall refrain from performing any act, engaging in any conduct or course of conduct or making or publishing an adverse, untrue or misleading statement which has, or may reasonably have, the effect of demeaning the name or business reputation of the Protected Parties or which adversely affects, or may be reasonably expected to adversely affect, the best interests, economic or otherwise, of the Protected Parties, except to the extent such statement or conduct may be required by law or legal process.

    The Company agrees that it shall direct its directors and executive officers to refrain from performing any act, engaging in any conduct or course of conduct, or making or publishing an adverse, untrue or misleading statement which has, or may reasonably have, the effect of demeaning the name or business reputation of Executive or which adversely affects, or may be reasonably expected to adversely affect, the best interests, economic or otherwise, of Executive, except to the extent such statement or conduct may be required by law or legal process.

2.4    Non-Solicitation of Customers. Executive agrees that during the Restricted Period, Executive shall not, directly or indirectly, for Executive's own benefit, on behalf of another, or to the detriment of the Protected Parties, solicit for any business purpose, divert, or attempt to solicit for any business purpose or attempt to divert, any customer of the Protected Parties, determined as of Executive's Separation Date, provided that this restriction on solicitation shall apply to any customer located or doing business in the Restricted Area or who isotherwise named by the Protected Parties on an exhibit hereto.

2.5    Non-Competition. Executive agrees that during the Restricted Period, Executive shall not carry on or engage in, whether directly or indirectly, and whether as a director, officer, employee, partner, contractor, consultant, agent or other advisor, a business that competes with the Company's Business (as defined below); provided that nothing contained herein shall prevent Executive from acquiring or holding less than 2% of the equity securities of a publicly-traded company that is engaged in the Company's Business. The foregoing covenant shall apply only to activities carried on in or related to the Restricted Area.

2.6    Restrictions Reasonable; Severable; Reformation Permitted. Executive agrees that each of the covenants set forth in this Section 2 is intended to constitute a separate restriction. Should any covenant be declared invalid or unenforceable, such covenant shall be deemed severable from and shall not affect the remainder thereof. Executive further agrees that the covenants set forth in this Section 2 are reasonable in both time and geographic scope. Should a court of law or arbitrator, as the case may be, determine that any covenant set forth herein is unenforceable, such covenant shall be deemed reformed to the minimum extent necessary to permit its enforcement.

2.7    Remedies. In the event of a breach, or threatened breach, by Executive of the covenants set forth in this Section 2, Executive agrees that the Company shall be entitled to a temporary restraining order or a preliminary injunction, without the requirement of bond, which may be obtained by means of a judicial proceeding or arbitration, as determined in the discretion of the Company. To the maximum extent permitted by law, Executive further acknowledges that the Company shall have no further obligation to provide any payment or benefit due to Executive, or his or her estate, spouse or dependents, under the Plan following such breach or threatened breach. Executive agrees that the remedies set forth here shall be in addition to any other legal remedy available to the Company, including damages.

3.    DEFINITIONS: Unless otherwise defined herein, capitalized termsshall have the meanings ascribed to them in the Plan, a copy of which has been furnished to Executive.

3.1    The term "Company's Business" shall mean the regulated electric utility business conducted within the State of Louisiana and the ownership and operation of merchant power facilities.

Page 3 of 6

3.2    The term "Restricted Area" shall mean the State of Louisiana, Parishes of Acadia, Allen, Avoyelles, Beauregard, Calcasieu, Catahoula, DeSoto, Evangeline, Grant, Iberia, Jefferson Davis, Lafayette, Natchitoches, Rapides, Red River, Sabine, St. Landry, St Martin, St. Mary, St. Tammany, Vernon, and Washington, and the State of Mississippi, Counties of Coahoma and Yazoo.

3.3    The term "Restricted Period" shall mean the number of months during which Executive's Severance Benefits are payable under the terms of the Plan (specified above), measured from Executive's Separation Date, but in no event more than 24 months.

4.    GENERAL PROVISIONS:

4.1    Arbitration. In addition to the Company's equitable remedies provided under paragraph 2.7 hereof, which need not be exclusively resolved by arbitration, in the event that any legal dispute arises in connection with, relating to, or concerning this Agreement, or in the event of any claim for breach or violation of any provision of this Agreement, Executive agrees that such dispute or claim will be resolved by arbitration. Any sucharbitration proceeding shall be conducted in accordance with the rulesof JAMS governing employment disputes. Any such dispute or claim will be presented to a single arbitrator selected by mutual agreement of Executive and the Company (or the arbitrator will be selected in accordance with the rules of JAMS). All determinations of the arbitrator will be final and binding upon Executive and the Company. Except as provided in Section 4.8 hereof, each party to the arbitration proceeding will bear its own fees and costs in connection with such arbitration proceedings, and the costs and expenses of the arbitrator will be divided evenly between such parties. The venue for any arbitration proceeding will be in Pineville, Louisiana and that the state and federal courts in Alexandria, Louisiana, shall have exclusion jurisdiction of any claim to which the arbitration provision in this Plan does not apply (including a judicial proceeding to enforce the Plan's arbitration provision), and the Executive consents to the personal jurisdiction of any such court.

4.2    Entire Agreement. This Agreement constitutes the final and complete understanding and agreement hereto with respect to the subject matter hereof, and there are no other agreements, understandings, restrictions, representations or warranties among Executive and the Protected Parties other than those set forth herein, provided that Executive shall remain bound to any confidentiality provisions contained in a handbook, policy or separate agreement with the Company or its Affiliates and Executive shall further be bound by the terms of any additional agreement entered into as a condition of payment under the Plan.

4.3    Amendment. This Agreement may be amended or modified at any time in any or all respects, but only by an instrument in writing executed by Executive and the Company.

4.4    Choice of Law. The validity of this Agreement, the construction of its terms, and the determination of the rights and obligations of Executive hereunder shall be governed by and construed in accordance with the internal laws of the State of Louisiana applicable to contracts made to be performed wholly within such state, without regard to the choice of law provisions thereof.

4.5    Notices. All notices and other communications under this Agreement must be in writing and will be deemed to have been duly given when (a) delivered by hand, (b) sent by a nationally recognized overnight delivery service (receipt requested), or (c) when received by the addressee, if sent first class mail, postage prepaid, in each case as follows

If to Executive    Addressed to Executive

Most Recent Address on File with the Company

Page 4 of 6

If to the Company.    Cleco Corporate Holdings LLC

2030 Donahue Ferry Road

Pineville, LA 71360

Attention General Counsel

or to such other address as Executive or the Company, as the case may be, may designate by notice to the other.

4.6    Successors and Assigns. This Agreement will inure to the benefit of, and be binding upon the Company, its successors and assigns, including, without limitation, any person, partnership, company, corporation or other entity that may acquire substantially all of the Company's assets or businesses or with or into which the Company may be liquidated, consolidated, merged or otherwise combined. This Agreement will be binding upon Executive, his or her heirs, estate, legatees and legal representatives.

4.7    Waiver. The failure of the Company to insist in any one or more instances upon performance of any terms or conditions of this Agreement will not be construed as a waiver of future performance of any such term, covenant, or condition and the obligations of either party with respect to such term, covenant or condition will continue in full force and effect.

4.8    Attorneys' Fees. Section 7.9 of the Plan, Attorneys' Fees, shall be deemed incorporated herein by this reference and shall be applicable in accordance with its terms to any proceeding or arbitration hereunder.

4.9    Executive's Acknowledgements. Executive understands that Section 1 of this Agreement constitutes a general waiver and release in favor of the Protected Parties, as more fully set forth therein. In connection with such waiver and release Executive acknowledges.

    a.    That he or she has been advised to consult an attorney before signing this Agreement and that Executive has done so or has determined that such consultation is not necessary.

    b.    That the Agreement was furnished to him or her on or before the date specified above (the "Delivery Date") and that he or she has 45 calendar days after the Delivery Date to consider whether to sign this Agreement, without alteration, and return it to the Company by first class mail or by hand delivery, and that if he or she executes and delivers this Agreement before the expiration of the 45-day period, Executive will be deemed to have waived the balance of the period.

    c.    That if Executive fails to execute and deliver this Agreement to the Company before the expiration of such 45-day period, he or she shall be deemed to have forfeited any right or benefit due to him or her under the Plan.

    d.    That he or she has been given an opportunity to review this Agreement, including the waiver and release included in Section 1 hereto, that he or she fully understands its provisions, and that he or she has voluntarily entered into this Agreement.

    e.    That he or she may revoke this Agreement by providing written notice to the Company by hand delivery or by U S mail, postage prepaid, in accordance with Section 4.5 hereof, during the seven-day period following its execution; thereafter, this Agreement shall be irrevocable. Executive acknowledges that if he or she revokes this Agreement, the Company shall have no obligation to provide the consideration offered under the Plan.

Page 5 of 6

THIS WAIVER, RELEASE AND COVENANTS AGREEMENT has been executed on this ___________day of ______________, 202___.

EXECUTIVE:     WITNESS:

_______________________________    __________________________________

Signature    Signature

_______________________________    __________________________________

Print Name     Print Name

Page 6 of 6

EX-31.1

CLECO CORPORATE HOLDINGS LLC EXHIBIT 31.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, William G. Fontenot, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2021, of Cleco Corporate Holdings LLC;

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

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

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

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

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

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

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

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

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

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

Date: August 11, 2021

/s/ William G. Fontenot

William G. Fontenot
President and Chief Executive Officer

EX-31.2

CLECO CORPORATE HOLDINGS LLC EXHIBIT 31.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, Kristin L. Guillory, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2021, of Cleco Corporate Holdings LLC;

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

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

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

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

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

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

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

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

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

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

Date: August 11, 2021

/s/ Kristin L. Guillory

Kristin L. Guillory
Chief Financial Officer

EX-31.3

CLECO POWER LLC          EXHIBIT 31.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, William G. Fontenot, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2021, of Cleco Power LLC;

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

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

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

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

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

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

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

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

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

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

Date:  August 11, 2021

/s/  William G. Fontenot

William G. Fontenot
Chief Executive Officer

EX-31.4

CLECO POWER LLC          EXHIBIT 31.4

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, Kristin L. Guillory, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2021, of Cleco Power LLC;

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

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

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

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

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

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

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

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

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

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

Date: August 11, 2021

/s/ Kristin L. Guillory

Kristin L. Guillory
Chief Financial Officer

EX-32.1

CLECO CORPORATE HOLDINGS LLC EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Corporate Holdings LLC (the “Company”) on Form 10-Q for the quarter ended June 30, 2021, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William G. Fontenot, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:   August 11, 2021

/s/  William G. Fontenot

William G. Fontenot
President and Chief Executive Officer

EX-32.2

CLECO CORPORATE HOLDINGS LLC EXHIBIT 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Corporate Holdings LLC (the “Company”) on Form 10-Q for the quarter ended June 30, 2021, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Kristin L. Guillory, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:  August 11, 2021

/s/ Kristin L. Guillory

Kristin L. Guillory
Chief Financial Officer

EX-32.3

CLECO POWER LLC EXHIBIT 32.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Power LLC (the “Company”) on Form 10-Q for the quarter ended
June 30, 2021, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William G. Fontenot, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:   August 11, 2021

/s/  William G. Fontenot

William G. Fontenot
Chief Executive Officer

EX-32.4

CLECO POWER LLC EXHIBIT 32.4

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Power LLC (the “Company”) on Form 10-Q for the quarter ended
June 30, 2021, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Kristin L. Guillory, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, as amended; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

Date:  August 11, 2021

/s/ Kristin L. Guillory

Kristin L. Guillory
Chief Financial Officer

XML

Cover Page	6 Months Ended
	Jun. 30, 2021 shares
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Jun. 30, 2021
Document Transition Report	false
Entity File Number	1-15759
Entity Registrant Name	CLECO CORPORATE HOLDINGS LLC
Entity Incorporation, State or Country Code	LA
Entity Tax Identification Number	72-1445282
Entity Address, Address Line One	2030 Donahue Ferry Road
Entity Address, City or Town	Pineville
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	71360-5226
City Area Code	318
Local Phone Number	484-7400
Entity Current Reporting Status	No
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	0
Entity Central Index Key	0001089819
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q2
Amendment Flag	false
CLECO POWER
Entity Information [Line Items]
Entity File Number	1-05663
Entity Registrant Name	CLECO POWER LLC
Entity Incorporation, State or Country Code	LA
Entity Tax Identification Number	72-0244480
Entity Address, Address Line One	2030 Donahue Ferry Road
Entity Address, City or Town	Pineville
Entity Address, State or Province	LA
Entity Address, Postal Zip Code	71360-5226
City Area Code	318
Local Phone Number	484-7400
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding	0
Entity Central Index Key	0000018672
Current Fiscal Year End Date	--12-31

XML

Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Operating revenue
Electric operations	$ 351,936	$ 321,956	$ 718,181	$ 633,113
Other operations	45,330	44,902	95,056	89,810
Affiliate revenue	0	0	0	0
Gross operating revenue	397,266	366,858	813,237	722,923
Electric customer credits	(18,517)	(9,100)	(39,494)	(17,593)
Operating revenue, net	378,749	357,758	773,743	705,330
Operating expenses
Fuel used for electric generation	25,482	67,864	81,302	144,501
Purchased power	90,494	59,505	235,196	125,825
Other operations and maintenance	72,815	71,798	144,978	146,564
Depreciation and amortization	54,318	54,087	109,265	109,960
Taxes other than income taxes	11,886	14,036	33,003	30,572
Merger transaction and commitment costs	(232)	274	(285)	3,049
Total operating expenses	254,763	267,564	603,459	560,471
Operating income	123,986	90,194	170,284	144,859
Interest income	829	898	1,475	2,054
Allowance for equity funds used during construction	1,105	127	1,991	53
Other (expense) income, net	(3,970)	257	(7,002)	(12,452)
Interest charges
Interest charges, net	33,826	35,023	67,918	70,350
Allowance for borrowed funds used during construction	(535)	(308)	(735)	(487)
Total interest charges	33,291	34,715	67,183	69,863
Income before income taxes	88,659	56,761	99,565	64,651
Federal and state income tax expense	9,837	13,593	416	15,155
Net income	78,822	43,168	99,149	49,496
CLECO POWER
Operating revenue
Electric operations	262,948	239,643	530,107	464,073
Other operations	16,269	15,904	34,895	31,668
Affiliate revenue	1,224	1,240	2,879	2,346
Gross operating revenue	280,441	256,787	567,881	498,087
Electric customer credits	(18,762)	(9,100)	(39,738)	(17,440)
Operating revenue, net	261,679	247,687	528,143	480,647
Operating expenses
Fuel used for electric generation	68,633	64,064	113,843	125,129
Purchased power	34,255	19,179	113,288	42,641
Other operations and maintenance	52,160	54,667	105,726	111,608
Depreciation and amortization	40,933	41,596	83,009	85,273
Taxes other than income taxes	7,314	9,448	23,816	21,725
Total operating expenses	203,295	188,954	439,682	386,376
Operating income	58,384	58,733	88,461	94,271
Interest income	825	755	1,468	1,709
Allowance for equity funds used during construction	1,105	127	1,991	53
Other (expense) income, net	(5,700)	(3,423)	(9,958)	(6,091)
Interest charges
Interest charges, net	18,772	18,911	37,618	37,671
Allowance for borrowed funds used during construction	(535)	(308)	(735)	(487)
Total interest charges	18,237	18,603	36,883	37,184
Income before income taxes	36,377	37,589	45,079	52,758
Federal and state income tax expense	8,956	9,356	(767)	12,694
Net income	$ 27,421	$ 28,233	$ 45,846	$ 40,064

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Net income	$ 78,822	$ 43,168	$ 99,149	$ 49,496
Other comprehensive income, net of tax
Postretirement benefits gain (loss), net of tax expense (benefit)	(420)	442	208	856
Total other comprehensive income (loss), net of tax	(420)	442	208	856
Comprehensive income, net of tax	78,402	43,610	99,357	50,352
CLECO POWER
Net income	27,421	28,233	45,846	40,064
Other comprehensive income, net of tax
Postretirement benefits gain (loss), net of tax expense (benefit)	287	419	745	845
Amortization of interest rate derivatives to earnings	64	64	128	128
Total other comprehensive income (loss), net of tax	351	483	873	973
Comprehensive income, net of tax	$ 27,772	$ 28,716	$ 46,719	$ 41,037

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Tax (expense) benefit of postretirement benefits gain (loss)	$ 148	$ (156)	$ (74)	$ (302)
CLECO POWER
Tax (expense) benefit of postretirement benefits gain (loss)	(101)	(148)	(263)	(299)
Tax expense on amortization of interest rate derivatives to earnings	$ 22	$ 22	$ 45	$ 45

XML

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Current assets
Cash and cash equivalents	$ 78,353	$ 84,976
Restricted cash and cash equivalents	2,949	4,545
Customer accounts receivable (less allowance for credit losses)	92,686	82,511
Accounts receivable - affiliate	2,686	1,663
Other accounts receivable	34,993	32,076
Taxes receivable	5,023	0
Unbilled revenue	44,308	40,127
Fuel inventory, at average cost	164,548	109,494
Materials and supplies, at average cost	135,494	132,449
Energy risk management assets	38,724	13,081
Accumulated deferred fuel	75,295	28,194
Cash surrender value of company-/trust-owned life insurance policies	94,684	89,138
Prepayments	16,616	14,549
Regulatory assets	24,699	21,041
Other current assets	16,563	11,048
Total current assets	827,621	664,892
Property, plant, and equipment
Property, plant, and equipment	5,446,409	5,337,190
Accumulated depreciation	(821,447)	(672,271)
Net property, plant, and equipment	4,624,962	4,664,919
Construction work in progress	157,419	124,622
Total property, plant, and equipment, net	4,782,381	4,789,541
Equity investment in investee	5,572	9,072
Goodwill	1,490,797	1,490,797
Prepayments	18,337	23,405
Operating lease right of use assets	25,315	26,172
Restricted cash and cash equivalents	744	744
Note receivable	14,134	14,506
Regulatory assets	626,527	554,609
Intangible assets	98,804	111,731
Other deferred charges	51,237	40,100
Total assets	7,941,469	7,725,569
Current liabilities
Short-term debt	160,000	75,000
Long-term debt and finance leases due within one year	66,718	66,682
Accounts payable	175,189	161,357
Accounts payable - affiliate	41,283	41,283
Customer deposits	60,092	58,718
Provision for rate refund	7,251	9,444
Taxes payable	32,502	7,530
Interest accrued	15,349	15,583
Energy risk management liabilities	1,161	2,453
Regulatory liabilities	44,862	23,509
Deferred compensation	13,563	13,240
Other current liabilities	54,326	49,813
Total current liabilities	672,296	524,612
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	694,046	661,376
Postretirement benefit obligations	316,330	314,653
Regulatory liabilities - deferred taxes, net	108,908	157,056
Deferred lease revenue	36,054	40,657
Intangible liabilities	21,517	24,859
Asset retirement obligations	27,404	27,986
Operating lease liabilities	22,315	23,333
Other deferred credits	24,180	28,627
Total long-term liabilities and deferred credits	1,250,754	1,278,547
Long-term debt and finance leases, net	3,162,039	3,165,387
Total liabilities	5,085,089	4,968,546
Commitments and contingencies (Note 13)
Member’s equity
Member’s equity	2,856,380	2,757,023
Total liabilities and member’s equity	7,941,469	7,725,569
CLECO POWER
Current assets
Cash and cash equivalents	20,767	24,846
Restricted cash and cash equivalents	2,949	4,545
Customer accounts receivable (less allowance for credit losses)	49,863	43,852
Accounts receivable - affiliate	13,026	14,605
Other accounts receivable	27,715	27,535
Unbilled revenue	44,308	40,127
Fuel inventory, at average cost	119,379	63,234
Materials and supplies, at average cost	108,022	105,340
Energy risk management assets	6,867	4,337
Accumulated deferred fuel	75,295	28,194
Cash surrender value of company-/trust-owned life insurance policies	16,230	16,184
Prepayments	7,189	7,163
Regulatory assets	16,964	13,305
Other current assets	5,551	830
Total current assets	514,125	394,097
Property, plant, and equipment
Property, plant, and equipment	5,915,689	5,824,378
Accumulated depreciation	(2,190,690)	(2,067,362)
Net property, plant, and equipment	3,724,999	3,757,016
Construction work in progress	146,232	110,613
Total property, plant, and equipment, net	3,871,231	3,867,629
Equity investment in investee	5,572	9,072
Prepayments	1,370	1,496
Operating lease right of use assets	25,263	26,006
Note receivable	14,134	14,506
Regulatory assets	491,487	414,535
Other deferred charges	24,239	38,806
Total assets	4,947,421	4,766,147
Current liabilities
Short-term debt	160,000	75,000
Long-term debt and finance leases due within one year	718	682
Accounts payable	135,352	106,089
Accounts payable - affiliate	70,437	72,068
Customer deposits	60,092	58,718
Provision for rate refund	7,251	8,630
Taxes payable	35,568	4,778
Interest accrued	5,108	5,357
Energy risk management liabilities	877	1,121
Regulatory liabilities	44,862	23,509
Other current liabilities	23,475	24,754
Total current liabilities	543,740	380,706
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	653,655	634,598
Postretirement benefit obligations	233,265	230,825
Regulatory liabilities - deferred taxes, net	108,908	157,056
Asset retirement obligations	11,529	11,364
Operating lease liabilities	22,282	23,295
Other deferred credits	17,289	18,167
Total long-term liabilities and deferred credits	1,046,928	1,075,305
Long-term debt and finance leases, net	1,502,155	1,502,257
Total capitalization	3,356,753	3,310,136
Commitments and contingencies (Note 13)
Member’s equity
Member’s equity	1,854,598	1,807,879
Total liabilities and member’s equity	$ 4,947,421	$ 4,766,147

XML

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Customer accounts receivable, allowance for credit losses	$ 1,334	$ 2,758
CLECO POWER
Customer accounts receivable, allowance for credit losses	$ 1,334	$ 2,758

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021		Jun. 30, 2020
Operating activities
Net income	$ 99,149		$ 49,496
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	124,750		124,797
Provision for credit losses	2,486		4,093
Unearned compensation expense	3,749		3,219
Allowance for equity funds used during construction	(1,991)		(53)
(Gain) loss on risk management assets and liabilities, net	(48,242)		(2,534)
Deferred lease revenue	(4,603)		(4,603)
Deferred income taxes	5,425		16,120
Cash surrender value of company-/trust-owned life insurance	(5,545)		5,790
Changes in assets and liabilities
Accounts receivable	(18,826)		(10,131)
Accounts receivable, affiliate	(1,023)		(32)
Unbilled revenue	(4,181)		(6,924)
Fuel inventory and materials and supplies	(57,899)		(46,816)
Prepayments	(7,555)		(12,438)
Accounts payable	12,768		(38,532)
Customer deposits	6,286		3,699
Provision for merger commitments	(1,143)		858
Postretirement benefit obligations	1,959		3,013
Regulatory assets and liabilities, net	(17,608)		(3,580)
Deferred fuel recoveries	(48,321)		(2,137)
Other deferred accounts	(8,745)		(6,030)
Taxes accrued	19,220		17,407
Interest accrued	(234)		(2,709)
Deferred compensation	323		(1,050)
Other operating	(4,737)		4,906
Net cash provided by operating activities	45,462		95,829
Investing activities
Additions to property, plant, and equipment	(140,507)		(139,339)
Allowance for equity funds used during construction	1,991		53
Return of equity investment in investee	1,750		0
Other investing	1,091		572
Net cash used in investing activities	(135,675)		(138,714)
Financing activities
Draws on revolving credit facilities	100,000		238,000
Payments on revolving credit facilities	(15,000)		0
Repayment of long-term debt	0		(11,055)
Payment of financing costs	(2,674)		(3,471)
Other financing	(332)		(300)
Net cash provided by financing activities	81,994		223,174
Net (decrease) increase in cash, cash equivalents, restricted cash, and restricted cash equivalents	(8,219)		180,289
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	90,265	[1]	142,595
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	82,046	[1]	322,884
Supplementary cash flow information
Interest paid, net of amount capitalized	62,947		65,658
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	3,547		7,851
Accrued distribution from equity investment in investee	1,750		0
CLECO POWER
Operating activities
Net income	45,846		40,064
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	85,844		88,034
Provision for credit losses	2,486		3,705
Unearned compensation expense	1,063		730
Allowance for equity funds used during construction	(1,991)		(53)
Deferred income taxes	(8,424)		6,091
Cash surrender value of company-/trust-owned life insurance	(46)		1,445
Changes in assets and liabilities
Accounts receivable	(11,775)		(15,462)
Accounts receivable, affiliate	3,368		2,573
Unbilled revenue	(4,181)		(6,924)
Fuel inventory and materials and supplies	(58,627)		(35,639)
Accounts payable	30,625		(30,242)
Accounts payable - affiliate	(1,763)		(3,149)
Customer deposits	6,286		3,699
Provision for merger commitments	(643)		(1,455)
Postretirement benefit obligations	1,661		1,800
Regulatory assets and liabilities, net	(18,602)		(4,574)
Deferred fuel recoveries	(48,321)		(2,137)
Other deferred accounts	(4,898)		(5,778)
Taxes accrued	30,062		23,517
Interest accrued	(249)		(2,056)
Other operating	(7,196)		2,299
Net cash provided by operating activities	40,525		66,488
Investing activities
Additions to property, plant, and equipment	(134,185)		(132,578)
Allowance for equity funds used during construction	1,991		53
Return of equity investment in investee	1,750		0
Other investing	1,091		572
Net cash used in investing activities	(129,353)		(131,953)
Financing activities
Draws on revolving credit facilities	100,000		150,000
Payments on revolving credit facilities	(15,000)		0
Repayment of long-term debt	0		(11,055)
Payment of financing costs	(1,515)		(1,123)
Other financing	(332)		(300)
Net cash provided by financing activities	83,153		137,522
Net (decrease) increase in cash, cash equivalents, restricted cash, and restricted cash equivalents	(5,675)		72,057
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	29,391	[2]	80,952
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	23,716	[2]	153,009
Supplementary cash flow information
Interest paid, net of amount capitalized	33,973		33,711
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	2,814		7,581
Accrued distribution from equity investment in investee	$ 1,750		$ 0

[1] (1) Includes cash and cash equivalents of $84,976, current restricted cash and cash equivalents of $4,545, and non-current restricted cash and cash equivalents of $744. (2) Includes cash and cash equivalents of $78,353, current restricted cash and cash equivalents of $2,949, and non-current restricted cash and cash equivalents of $744.

[2] (1) Includes cash and cash equivalents of $24,846 and current restricted cash and cash equivalents of $4,545. (2) Includes cash and cash equivalents of $20,767 and current restricted cash and cash equivalents of $2,949.

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Cash and cash equivalents	$ 78,353	$ 84,976
Restricted cash and cash equivalents, current	2,949	4,545
Restricted cash and cash equivalents, noncurrent	744	744
CLECO POWER
Cash and cash equivalents	20,767	24,846
Restricted cash and cash equivalents, current	$ 2,949	$ 4,545

XML

Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited) - USD ($) $ in Thousands	Total	MEMBERSHIP INTEREST	RETAINED EARNINGS	AOCI	CLECO POWER	CLECO POWER MEMBERSHIP INTEREST	CLECO POWER AOCI
Balances, beginning of period at Dec. 31, 2019	$ 2,643,006	$ 2,454,276	$ 206,243	$ (17,513)	$ 1,713,392	$ 1,735,977	$ (22,585)
Increase (Decrease) in Equity [Roll Forward]
Net income	49,496		49,496		40,064	40,064
Other comprehensive income (loss), net of tax	856			856	973		973
Balances, end of period at Jun. 30, 2020	2,693,358	2,454,276	255,739	(16,657)	1,754,429	1,776,041	(21,612)
Balances, beginning of period at Mar. 31, 2020	2,649,748	2,454,276	212,571	(17,099)	1,725,713	1,747,808	(22,095)
Increase (Decrease) in Equity [Roll Forward]
Net income	43,168		43,168		28,233	28,233
Other comprehensive income (loss), net of tax	442			442	483		483
Balances, end of period at Jun. 30, 2020	2,693,358	2,454,276	255,739	(16,657)	1,754,429	1,776,041	(21,612)
Balances, beginning of period at Dec. 31, 2020	2,757,023	2,454,276	328,543	(25,796)	1,807,879	1,832,632	(24,753)
Increase (Decrease) in Equity [Roll Forward]
Net income	99,149		99,149		45,846	45,846
Other comprehensive income (loss), net of tax	208			208	873		873
Balances, end of period at Jun. 30, 2021	2,856,380	2,454,276	427,692	(25,588)	1,854,598	1,878,478	(23,880)
Balances, beginning of period at Mar. 31, 2021	2,777,978	2,454,276	348,870	(25,168)	1,826,826	1,851,057	(24,231)
Increase (Decrease) in Equity [Roll Forward]
Net income	78,822		78,822		27,421	27,421
Other comprehensive income (loss), net of tax	(420)			(420)	351		351
Balances, end of period at Jun. 30, 2021	$ 2,856,380	$ 2,454,276	$ 427,692	$ (25,588)	$ 1,854,598	$ 1,878,478	$ (23,880)

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Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 2021

Accounting Policies [Abstract]

Summary of Significant Accounting Policies

Note 1 — Summary of Significant Accounting Policies

COVID-19 Impacts

In March 2020, WHO declared the outbreak of COVID-19 to be a global pandemic, and the U.S. declared a national emergency. In response to these declarations and the rapid spread of COVID-19, federal, state and local governments imposed varying degrees of restrictions on business and social activities to contain COVID-19, including quarantine and “stay-at-home” orders and directives in Cleco’s service territory. State and local authorities also subsequently implemented multistep policies to reopen various sectors of the economy such as retail establishments, health and personal care businesses, and restaurants, among others. During March and April 2021, due to the reduction in new COVID-19 cases and hospitalizations and the availability of COVID-19 vaccines, the governor of the state of Louisiana reduced restrictions that were previously in effect, eased capacity limits on businesses and social gatherings, and revoked the mandatory, state-wide mask mandate. However, effective August 4, 2021, the state-wide mask mandate was reinstated due to a surge in COVID-19 cases.

The COVID-19 pandemic may worsen in the U.S. during the upcoming months, which may cause federal, state, and local governments to reconsider restrictions on business and social activities. In the event governments reinstate or increase restrictions, the reopening of the economy may be further curtailed.

Cleco has modified some of its business operations, as these restrictions have significantly impacted many sectors of the economy. Impacts include record levels of unemployment, with businesses, nonprofit organizations, and governmental entities modifying, curtailing, or ceasing normal operations. Cleco is monitoring the ongoing COVID-19 pandemic and continues to adjust certain business practices to conform to government restrictions and best practices encouraged by the CDC, WHO, and other governmental and regulatory authorities.

Cleco cannot predict the full impact that COVID-19, or the significant disruption and volatility currently being experienced in the markets, will have on its business, cash flows, liquidity, financial condition, and results of operations at this time, due to numerous uncertainties. The ultimate impacts will depend on future developments, including, among others, the ultimate geographic spread of COVID-19, the consequences of governmental and other measures designed to prevent the spread of COVID-19, the availability, timely distribution and acceptance of effective treatments and vaccines, the duration of the pandemic, actions taken by governmental authorities, customers, suppliers and other third parties, workforce availability, and the timing and extent to which normal economic and operating conditions resume.

Principles of Consolidation

The accompanying condensed consolidated financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Basis of Presentation

The condensed consolidated financial statements of Cleco and Cleco Power have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these condensed consolidated financial statements do not include all of the information and notes required by GAAP for annual financial statements. The year-end condensed consolidated balance sheet data was derived from audited financial statements. Because the interim condensed consolidated financial statements and the accompanying notes do not include all of the information and notes required by GAAP for annual financial statements, the condensed consolidated financial statements and other information included in this Quarterly Report on Form 10-Q should be read in conjunction with the consolidated financial statements and accompanying notes in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020.

These condensed consolidated financial statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly state the financial position and results of operations of Cleco and Cleco Power. Amounts reported in Cleco and Cleco Power’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, discrete income tax items, and other factors.

In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates. For information on recent authoritative guidance and its effect on financial results, see Note 2 — “Recent Authoritative Guidance.”

Restricted Cash and Cash Equivalents

Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general corporate purposes.

Cleco and Cleco Power’s restricted cash and cash equivalents consisted of the following:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current
Cleco Katrina/Rita’s storm recovery bonds	$	1,673	$	2,626
Cleco Power’s charitable contributions	1,078		1,718
Cleco Power’s rate credit escrow	198		201
Total current	2,949		4,545
Non-current
Diversified Lands’ mitigation escrow	22		22
Cleco Cajun’s defense fund	722		722
Total non-current	744		744
Total restricted cash and cash equivalents	$	3,693	$	5,289

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current
Cleco Katrina/Rita’s storm recovery bonds	$	1,673	$	2,626
Charitable contributions	1,078		1,718
Rate credit escrow	198		201
Total restricted cash and cash equivalents	$	2,949	$	4,545

Prior to the repayment of the storm recovery bonds in March 2020, Cleco Katrina/Rita had the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash was collected, it was restricted for payment of administrative fees, interest, and principal on the storm recovery bonds. The remaining $1.7 million of restricted cash relating to Cleco Katrina/Rita at June 30, 2021, will be used to benefit retail customers in a manner and timing as approved by the LPSC.

Reserves for Credit Losses

Customer accounts receivable are recorded at the invoiced amount and do not bear interest. Customer accounts receivable are generally considered to become past due 20 days after the billing date. Cleco recognizes write-offs within the allowance for credit losses once all recovery methods have been exhausted. It is the policy of management to review accounts receivable and unbilled revenue monthly using a reserve matrix based on historical bad debt write-offs, as well as current and forecasted economic conditions, to establish a credit loss estimate. Management’s historical credit loss analysis included periods of economic recessions, natural disasters, and temporary changes to collection policies. Due to the critical necessity of electricity, none of these past events have significantly impacted Cleco’s credit loss rates.

Although Cleco’s service territory experienced a recent decline in the economy in 2020 and 2021 primarily related to the COVID-19 pandemic and weather-related events, the economic outlook at June 30, 2021, was still within range of its historical credit loss analysis.

The tables below present the changes in the allowance for credit losses by receivable for Cleco and Cleco Power:

Cleco
			FOR THE THREE MONTHS  ENDED JUNE 30, 2021						FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	ACCOUNTS RECEIVABLE		OTHER*		TOTAL		ACCOUNTS RECEIVABLE		OTHER*		TOTAL
Balances, beginning of period	$	2,040	$	1,638	$	3,678	$	2,758	$	1,638	$	4,396
Current period provision	616		—		616		2,490		—		2,490
Charge-offs	(1,583)		—		(1,583)		(4,442)		—		(4,442)
Recovery	261		—		261		528		—		528
Balances, June 30, 2021	$	1,334	$	1,638	$	2,972	$	1,334	$	1,638	$	2,972

* Loan held at Diversified Lands that was fully reserved for at June 30, 2021.

			FOR THE THREE MONTHS  ENDED JUNE 30, 2020						FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE		OTHER*		TOTAL		ACCOUNTS RECEIVABLE		OTHER*		TOTAL
Balances, beginning of period	$	2,123	$	1,638	$	3,761	$	3,005	$	1,250	$	4,255
CECL adoption	—		—		—		71		—		71
Current period provision	1,137		—		1,137		3,634		388		4,022
Charge-offs	—		—		—		(4,091)		—		(4,091)
Recovery	226		—		226		867		—		867
Balances, June 30, 2020	$	3,486	$	1,638	$	5,124	$	3,486	$	1,638	$	5,124

* Loan held at Diversified Lands that was fully reserved for at June 30, 2020.

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2021		FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	ACCOUNTS RECEIVABLE
Balances, beginning of period	$	2,040	$	2,758
Current period provision	616		2,490
Charge-offs	(1,583)		(4,442)
Recovery	261		528
Balances, June 30, 2021	$	1,334	$	1,334

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Recent Authoritative Guidance

6 Months Ended

Jun. 30, 2021

Accounting Changes and Error Corrections [Abstract]

Recent Authoritative Guidance

Note 2 — Recent Authoritative Guidance

In March 2020, FASB issued optional guidance for a limited period of time that applies to entities meeting certain criteria for the contract modifications or hedging relationships that are referencing LIBOR or another reference rate expected to be discontinued due to reference rate reform. The guidance includes a general principal that permits an entity to consider contract modifications due to reference rate reform to be an event that does not require contract remeasurement at the modification date or reassessment of a previous accounting determination. The optional guidance may be applied from March 12, 2020, through December 31, 2022. Management has identified contracts with reference rates that will be discontinued, primarily related to long-term debt obligations. In the second quarter of 2021, certain debt contracts were amended to include fallback provisions that provide substitute reference rates upon the discontinuance of LIBOR, among other amendments. Management will continue to modify

contracts to include similar fallback language and expects to apply this guidance on an ongoing basis. Management does not expect this guidance to have a significant impact on the Registrants’ results of operations, financial condition, or cash flows.

In December 2019, FASB amended the guidance for accounting for income taxes. The amendments simplify the accounting for income taxes by removing certain exceptions to general principles included in the accounting guidance. Effective January 1, 2021, Cleco adopted the amended accounting guidance. Adoption of this guidance did not materially impact the Registrants’ results of operations, financial condition, or cash flows.

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Leases

6 Months Ended

Jun. 30, 2021

Leases [Abstract]

Leases

Note 3 — Leases

Cleco maintains operating and finance leases in its ordinary course of business activities.

Cottonwood Sale Leaseback Agreement

Upon closing the Cleco Cajun Transaction, the Cottonwood Sale Leaseback was executed. Under the terms of the lease, NRG Energy will operate the Cottonwood Plant, incur all costs, and receive all revenues from the operations of the plant. Cottonwood Energy will receive fixed lease payments of $40.0 million per year and variable lease payments for LTSA costs and property taxes paid by NRG Energy on behalf of Cleco. Cleco may terminate the lease contract under specific circumstances stated in the lease contract. The residual value under the Cottonwood Sale Leaseback is expected to be recovered through sales of power generation from the plant. The residual value of the Cottonwood Plant has been determined using the plant’s estimated economic life.

Cleco Cajun is Cleco’s only entity with lessor arrangements. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback is included in Other operations within Cleco’s Condensed Consolidated Statement of Income. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback for the three and six months ended June 30, 2021, and 2020, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE. 30,
(THOUSANDS)	2021		2020		2021		2020
Fixed payments	$	10,000	$	10,000	$	20,000	$	20,000
Variable payments	5,010		5,194		10,475		10,760
Amortization of deferred lease liability*	2,301		2,301		4,603		4,603
Total lease income	$	17,311	$	17,495	$	35,078	$	35,363

* Consists of amortization of the deferred lease revenue resulting from the fair value of the lease between Cottonwood Energy and a special-purpose entity that is a subsidiary of NRG Energy.

Leases

Note 3 — Leases

Cleco maintains operating and finance leases in its ordinary course of business activities.

Cottonwood Sale Leaseback Agreement

Upon closing the Cleco Cajun Transaction, the Cottonwood Sale Leaseback was executed. Under the terms of the lease, NRG Energy will operate the Cottonwood Plant, incur all costs, and receive all revenues from the operations of the plant. Cottonwood Energy will receive fixed lease payments of $40.0 million per year and variable lease payments for LTSA costs and property taxes paid by NRG Energy on behalf of Cleco. Cleco may terminate the lease contract under specific circumstances stated in the lease contract. The residual value under the Cottonwood Sale Leaseback is expected to be recovered through sales of power generation from the plant. The residual value of the Cottonwood Plant has been determined using the plant’s estimated economic life.

Cleco Cajun is Cleco’s only entity with lessor arrangements. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback is included in Other operations within Cleco’s Condensed Consolidated Statement of Income. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback for the three and six months ended June 30, 2021, and 2020, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE. 30,
(THOUSANDS)	2021		2020		2021		2020
Fixed payments	$	10,000	$	10,000	$	20,000	$	20,000
Variable payments	5,010		5,194		10,475		10,760
Amortization of deferred lease liability*	2,301		2,301		4,603		4,603
Total lease income	$	17,311	$	17,495	$	35,078	$	35,363

* Consists of amortization of the deferred lease revenue resulting from the fair value of the lease between Cottonwood Energy and a special-purpose entity that is a subsidiary of NRG Energy.

Leases

Note 3 — Leases

Cleco maintains operating and finance leases in its ordinary course of business activities.

Cottonwood Sale Leaseback Agreement

Upon closing the Cleco Cajun Transaction, the Cottonwood Sale Leaseback was executed. Under the terms of the lease, NRG Energy will operate the Cottonwood Plant, incur all costs, and receive all revenues from the operations of the plant. Cottonwood Energy will receive fixed lease payments of $40.0 million per year and variable lease payments for LTSA costs and property taxes paid by NRG Energy on behalf of Cleco. Cleco may terminate the lease contract under specific circumstances stated in the lease contract. The residual value under the Cottonwood Sale Leaseback is expected to be recovered through sales of power generation from the plant. The residual value of the Cottonwood Plant has been determined using the plant’s estimated economic life.

Cleco Cajun is Cleco’s only entity with lessor arrangements. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback is included in Other operations within Cleco’s Condensed Consolidated Statement of Income. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback for the three and six months ended June 30, 2021, and 2020, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE. 30,
(THOUSANDS)	2021		2020		2021		2020
Fixed payments	$	10,000	$	10,000	$	20,000	$	20,000
Variable payments	5,010		5,194		10,475		10,760
Amortization of deferred lease liability*	2,301		2,301		4,603		4,603
Total lease income	$	17,311	$	17,495	$	35,078	$	35,363

* Consists of amortization of the deferred lease revenue resulting from the fair value of the lease between Cottonwood Energy and a special-purpose entity that is a subsidiary of NRG Energy.

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Revenue Recognition

6 Months Ended

Jun. 30, 2021

Revenue from Contract with Customer [Abstract]

Revenue Recognition

Note 4 — Revenue Recognition

Operating revenue, net for the three and six months ended June 30, 2021, and 2020, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	105,315		$	—		$	—		$	—	$	105,315
Commercial (1)	68,392			—			—			—		68,392
Industrial (1)	37,385			—			—			—		37,385
Other retail (1)	3,876			—			—			—		3,876
Electric customer credits	(19,054)			—			—			—		(19,054)
Total retail revenue	195,914			—			—			—		195,914
Wholesale, net	46,216		(1)	91,407			(2,420)		(2)			135,203
Transmission, net	13,313		(3)	13,573		(4)	—			(1,595)		25,291
Other	3,249			—			—			—		3,249
Affiliate (5)	1,224			—			26,120			(27,344)		—
Total revenue from contracts with customers	259,916			104,980			23,700			(28,939)		359,657
Revenue unrelated to contracts with customers
Other	1,763		(6)	17,326		(7)	1			2		19,092
Total revenue unrelated to contracts with customers	1,763			17,326			1			2		19,092
Operating revenue, net	$	261,679		$	122,306		$	23,701		$	(28,937)	$	378,749

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $(0.3) million of electric customer credits.

(4) Includes $(0.2) million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $15.0 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization.

	FOR THE THREE MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	97,973		$	—		$	—		$	—	$	97,973
Commercial (1)	61,575			—			—			—		61,575
Industrial (1)	29,208			—			—			—		29,208
Other retail (1)	3,341			—			—			—		3,341
Electric customer credits	(8,423)			—			—			—		(8,423)
Total retail revenue	183,674			—			—			—		183,674
Wholesale, net	45,694		(1)	84,733			(2,420)		(2)	—		128,007
Transmission, net	11,625		(3)	13,131			—			(1,639)		23,117
Other	3,601			—			—			—		3,601
Affiliate (4)	1,240			43			29,138			(30,421)		—
Total revenue from contracts with customers	245,834			97,907			26,718			(32,060)		338,399
Revenue unrelated to contracts with customers
Other	1,853		(5)	17,505		(6)	1			—		19,359
Total revenue unrelated to contracts with customers	1,853			17,505			1			—		19,359
Operating revenue, net	$	247,687		$	115,412		$	26,719		$	(32,060)	$	357,758

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $0.7 million of electric customer credits.

(4) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(5) Realized gains associated with FTRs.

(6) Includes $15.2 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization.

	FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	200,396		$	—		$	—		$	—	$	200,396
Commercial (1)	131,418			—			—			—		131,418
Industrial (1)	74,051			—			—			—		74,051
Other retail (1)	7,446			—			—			—		7,446
Electric customer credits	(40,030)			—			—			—		(40,030)
Total retail revenue	373,281			—			—			—		373,281
Wholesale, net	107,938		(1)	192,914			(4,840)		(2)	—		296,012
Transmission, net	27,295		(3)	28,830		(4)	—			(3,535)		52,590
Other	7,891			—			—			—		7,891
Affiliate (5)	2,879			—			53,276			(56,155)		—
Total revenue from contracts with customers	519,284			221,744			48,436			(59,690)		729,774
Revenue unrelated to contracts with customers
Other	8,859		(6)	35,108		(7)	2			—		43,969
Total revenue unrelated to contracts with customers	8,859			35,108			2			—		43,969
Operating revenue, net	$	528,143		$	256,852		$	48,438		$	(59,690)	$	773,743

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $(0.3) million of electric customer credits.

(4) Includes $(0.2) million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $30.5 million in lease revenue related to the Cottonwood Sale Leaseback and $4.6 million of deferred lease revenue amortization.

	FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	179,544		$	—		$	—		$	—	$	179,544
Commercial (1)	122,685			—			—			—		122,685
Industrial (1)	61,418			—			—			—		61,418
Other retail (1)	6,802			—			—			—		6,802
Surcharge	2,443			—			—			—		2,443
Electric customer credits	(16,763)			—			—			—		(16,763)
Total retail revenue	356,129			—			—			—		356,129
Wholesale, net	87,923		(1)	173,880			(4,840)		(2)	—		256,963
Transmission, net	23,694		(3)	26,062		(4)	—			(3,456)		46,300
Other	7,296			—			—			—		7,296
Affiliate (5)	2,346			204			58,415			(60,965)		—
Total revenue from contracts with customers	477,388			200,146			53,575			(64,421)		666,688
Revenue unrelated to contracts with customers
Other	3,259		(6)	35,382		(7)	1			—		38,642
Total revenue unrelated to contracts with customers	3,259			35,382			1			—		38,642
Operating revenue, net	$	480,647		$	235,528		$	53,576		$	(64,421)	$	705,330

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $0.7 million of electric customer credits.

(4) Includes $0.2 million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $30.8 million in lease revenue related to the Cottonwood Sale Leaseback and $4.6 million of deferred lease revenue amortization.

Cleco and Cleco Power have unsatisfied performance obligations under contracts with cooperatives and municipalities with durations ranging between 1 and 14 years that primarily relate to stand-ready obligations as part of fixed capacity minimums. At June 30, 2021, Cleco and Cleco Power had $68.2 million of unsatisfied fixed performance obligations that will be recognized as revenue over the term of such contracts as the stand-ready obligation to provide energy is provided.

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Regulatory Assets and Liabilities

6 Months Ended

Jun. 30, 2021

Regulated Operations [Abstract]

Regulatory Assets and Liabilities

Note 5 — Regulatory Assets and Liabilities

Cleco Power capitalizes or defers certain costs for recovery from customers and recognizes a liability for amounts expected to be returned to customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered or refunded through the ratemaking process.

Under the current regulatory environment, Cleco Power believes these regulatory assets will be fully recoverable; however, if in the future, as a result of regulatory changes or

competition, Cleco Power’s ability to recover these regulatory assets would no longer be probable, then to the extent that such regulatory assets were determined not to be recoverable, Cleco Power would be required to write-down such assets. In addition, potential deregulation of the industry or possible future changes in the method of rate regulation of Cleco Power could require discontinuance of the application of the authoritative guidance on regulated operations.

The following table summarizes Cleco Power’s regulatory assets and liabilities:

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Regulatory assets
Acadia Unit 1 acquisition costs	$	1,966	$	2,019
Accumulated deferred fuel	75,295		28,194
AFUDC equity gross-up *	68,122		69,670
Affordability study	13,644		—
AMI deferred revenue requirement	2,318		2,591
AROs	7,202		5,488
Coughlin transaction costs	861		876
COVID-19 executive order	2,953		2,953
Deferred storm restoration costs -   Hurricane Delta	17,802		17,051
Deferred storm restoration costs -   Hurricane Laura	56,412		54,406
Deferred storm restoration costs -   Hurricane Zeta	3,494		3,493
Deferred storm restoration costs -   Winter Storms Uri & Viola	1,980		—
Dolet Hills Power Station closure costs	91,479		48,982
Dolet Hills Mine closure costs	13,910		—
Emergency declarations	—		270
Energy efficiency	2,350		2,820
Financing costs	7,011		7,184
Interest costs	3,583		3,708
Madison Unit 3 property taxes	4,181		—
Non-service cost of postretirement benefits	10,881		9,901
Other	13,040		4,229
Postretirement costs	155,067		165,437
Production operations and maintenance expenses	2,664		4,058
Rodemacher Unit 2 deferred costs	4,115		1,333
St. Mary Clean Energy Center	6,959		3,479
Training costs	6,007		6,085
Tree trimming costs	10,450		11,807
Total regulatory assets	583,746		456,034
Regulatory liabilities
AFUDC	(5,359)		(4,218)
Corporate franchise tax, net	—		(763)
Deferred taxes, net	(148,411)		(175,584)
Total regulatory liabilities	(153,770)		(180,565)
Total regulatory assets, net	$	429,976	$	275,469
* Represents regulatory assets for past expenditures that were not earning a return on investment at June 30, 2021, and December 31, 2020, respectively. All other assets are earning a return on investment.

The following table summarizes Cleco’s net regulatory assets and liabilities:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Total Cleco Power regulatory assets, net	$	429,976	$	275,469
2016 Merger adjustments *
Fair value of long-term debt	115,852		119,553
Postretirement costs	14,418		15,411
Financing costs	7,419		7,592
Debt issuance costs	5,086		5,254
Total Cleco regulatory assets, net	$	572,751	$	423,279

* Cleco regulatory assets include acquisition accounting adjustments as a result of the 2016 Merger.

Accumulated Deferred Fuel

In February 2021, Winter Storms Uri and Viola moved through Louisiana causing substantial damage to Cleco’s distribution assets, electricity generation supply shortages, natural gas supply shortages, and increases in wholesale prices of natural gas in the United States, primarily due to prolonged freezing temperatures. Incremental fuel and purchased power costs were incurred as a result of the winter storms. On March 29, 2021, Cleco Power received approval from the LPSC to recover $50.0 million of these costs through Cleco Power’s FAC over a period of 12 months beginning in May 2021. For more information about the incremental fuel and purchased power costs related to Winter Storms Uri and Viola, see Note 17 — “Storm Restoration — Winter Storms Uri and Viola.”

Affordability Study

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan. As a result, Cleco Power was allowed to establish a regulatory asset of $13.6 million related to outside consulting fees for the assessment of Cleco Power’s practices and assistance in the identification of potential cost savings opportunities, while maintaining superior levels of employee safety, reliability, customer service, environmental stewardship, community involvement, and regulatory transparency. The regulatory asset is being amortized over 10 years beginning July 1, 2021.

Deferred Storm Restoration Costs — Winter Storms

In February 2021, Cleco Power’s service territory experienced extreme and unprecedented winter weather.

On February 14, 2021, Winter Storm Uri reached Louisiana resulting in power outages for approximately 11,000 of Cleco Power’s electric customers located primarily in south Louisiana.

On February 17, 2021, Winter Storm Viola reached Louisiana resulting in power outages for approximately 43,000 of Cleco Power’s electric customers located primarily in central and south Louisiana.

On March 17, 2021, the LPSC approved utilities establishing a regulatory asset to track and defer non-capital expenses associated with these winter storms. For more information about Winter Storms Uri and Viola, see Note 17 — “Storm Restoration — Winter Storms Uri and Viola.”

Dolet Hills Mine Closure Cost

On March 17, 2021, the LPSC approved the establishment of a regulatory asset for lignite costs that exceeded $150 per ton that would otherwise be billed through Cleco Power’s FAC and any reasonable incremental third-party professional costs

related to the closure of the mine. At June 30, 2021, Cleco Power had a regulatory asset of $13.9 million for these mine-related incurred costs.

Madison Unit 3 Property Taxes

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan. As a result, beginning July 1, 2022, Cleco Power will be allowed to recover property taxes paid for Madison Unit 3, including a carrying charge at Cleco Power’s weighted average cost of capital, grossed up for taxes. At June 30, 2021, Cleco Power recorded a regulatory asset of $4.2 million for the accrued 2021 Madison Unit 3 property taxes. The amount included in the cost recovery mechanism each year will amortize over 12 months.

Other

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan resulting in Cleco Power establishing several regulatory assets. Cleco Power was allowed to establish a regulatory asset to recover the undercollection of revenues related to the Northlake Transmission Agreement. At June 30, 2021, Cleco Power had $3.5 million recorded for this regulatory asset, which is being amortized over 12 months beginning July 1, 2021. In addition, the LPSC approved recovery of other previously deferred costs totaling $4.1 million which are being amortized over four years beginning July 1, 2021. These costs are primarily associated with Cleco Power’s recently approved base rate case.

In June 2017 and prior to the approval of Cleco Power’s new retail rate plan, the LPSC approved the establishment of a regulatory asset upon the completion of the Coughlin Pipeline project for the revenue requirement associated with the project until Cleco Power’s new retail rate plan was approved. At June 30, 2021, Cleco Power had a regulatory asset of $5.4 million related to the deferred revenue associated with the Coughlin Pipeline project. As approved by the LPSC in Cleco Power’s new rate plan, the regulatory asset is being amortized over four years beginning July 1, 2021.

St. Mary Clean Energy Center

At June 30, 2021, Cleco Power had a regulatory asset of $7.0 million for revenue requirements related to the St. Mary Clean Energy Center. As approved by the LPSC in Cleco Power’s new retail rate plan, the regulatory asset is being amortized over four years beginning July 1, 2021.

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Fair Value Accounting

6 Months Ended

Jun. 30, 2021

Fair Value Disclosures [Abstract]

Fair Value Accounting

Note 6 — Fair Value Accounting

The amounts reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021, and December 31, 2020, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, short-term debt, and accounts payable approximate fair value because of their short-term nature. Cleco applies the provisions of the fair value measurement standard to its non-recurring, non-financial measurements including business combinations, as well as impairment related to goodwill and other long-lived assets.

The following tables summarize the carrying value and estimated market value of Cleco and Cleco Power’s financial instruments not measured at fair value on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets:

Cleco
	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	3,226,952	$	3,509,555	$	3,230,500	$	3,541,349

* The carrying value of long-term debt does not include deferred issuance costs of $12.8 million at
June 30, 2021, and $13.4 million at December 31, 2020.

Cleco Power
	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,495,101	$	1,772,243	$	1,494,947	$	1,794,799

* The carrying value of long-term debt does not include deferred issuance costs of $6.9 million at
June 30, 2021, and $7.0 million at December 31, 2020.

In order to fund capital requirements, Cleco issues fixed and variable rate long-term debt with various tenors. The fair value of this class fluctuates as the market interest rates for fixed and variable rate debt with similar tenors and credit ratings change. The fair value of the debt could also change from period to period due to changes in the credit rating of the Cleco entity by which the debt was issued. The fair value of long-term debt is classified as Level 2 in the fair value hierarchy.

Fair Value Measurements and Disclosures

Cleco classifies assets and liabilities that are measured at their fair value according to three different levels depending on the inputs used in determining fair value. Cleco elects not to designate derivatives as cash flow or fair value hedges, as allowed by accounting guidance. Cleco utilizes a mark-to-market approach recognizing changes in the fair value of FTRs and other commodity derivatives at Cleco Cajun in earnings and changes in the fair value of FTRs at Cleco Power as a component of deferred fuel assets and liabilities. Cleco utilizes different valuation techniques for fair value measurements under a fair value hierarchy. Assets and liabilities classified as Level 1 under the hierarchy utilize observable inputs that reflect quotable prices in active markets. Assets and liabilities classified as Level 2 are measured through proxy inputs of similar index or composite pricing. Assets and liabilities classified as Level 3 under the hierarchy are valued based on unobservable inputs, such as internally generated valuation models or valuations obtained in inactive markets where there is no readily available information. Cleco has consistently applied the Level 2 and Level 3 fair value techniques from fiscal period to fiscal period. Significant increases or decreases in any of those inputs in isolation would result in a significantly different fair value measurement. The assets and liabilities reported at fair value are grouped into classes based on the underlying nature and risks associated with the individual asset or liability.

The following tables disclose for Cleco and Cleco Power the fair value of financial assets and liabilities measured on a recurring basis:

Cleco
	FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS)	AT JUNE 30, 2021		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2020		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset description
Institutional money market funds	$	77,105	$	—	$	77,105	$	—	$	86,001	$	—	$	86,001	$	—
FTRs	8,662		—		—		8,662		4,805		—		—		4,805
Other commodity derivatives*	55,834		—		55,834		—		8,599		—		8,599		—
Total assets	$	141,601	$	—	$	132,939	$	8,662	$	99,405	$	—	$	94,600	$	4,805
Liability description
FTRs	$	1,161	$	—	$	—	$	1,161	$	1,625	$	—	$	—	$	1,625
Other commodity derivatives*	—		—		—		—		1,612		—		1,612		—
Total liabilities	$	1,161	$	—	$	—	$	1,161	$	3,237	$	—	$	1,612	$	1,625

* Other commodity derivatives include fixed price physical forwards and swap transactions.

Cleco Power
	FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS)	AT JUNE 30, 2021		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2020		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset description
Institutional money market funds	$	19,061	$	—	$	19,061	$	—	$	25,357	$	—	$	25,357	$	—
FTRs	6,867		—		—		6,867		4,337		—		—		4,337
Total assets	$	25,928	$	—	$	19,061	$	6,867	$	29,694	$	—	$	25,357	$	4,337
Liability description
FTRs	$	877	$	—	$	—	$	877	$	1,121	$	—	$	—	$	1,121
Total liabilities	$	877	$	—	$	—	$	877	$	1,121	$	—	$	—	$	1,121

The following tables summarize the net changes in the net fair value of FTR assets and liabilities classified as Level 3 in the fair value hierarchy for Cleco and Cleco Power:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Beginning balance	$	1,023	$	1,096	$	3,180	$	5,778
Unrealized (losses) gains*	(1,005)		(284)		15,155		(371)
Purchases	9,958		9,267		10,806		9,732
Settlements	(2,475)		(2,039)		(21,640)		(7,099)
Ending balance	$	7,501	$	8,040	$	7,501	$	8,040
* Cleco Power’s unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet. Cleco Cajun’s unrealized (losses) gains are reported through Purchased power on Cleco’s Condensed Consolidated Income Statement.

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Beginning balance	$	1,088	$	1,149	$	3,216	$	5,725
Unrealized (losses)gains*	(402)		1,298		(402)		1,298
Purchases	7,768		7,311		8,616		7,776
Settlements	(2,464)		(2,247)		(5,440)		(7,288)
Ending balance	$	5,990	$	7,511	$	5,990	$	7,511
* Unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheet.

The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions for Cleco and Cleco Power as of June 30, 2021, and December 31, 2020:

Cleco
	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW		HIGH
FTRs at June 30, 2021	$	8,662	$	1,161	RTO auction pricing	FTR price - per MWh	$	(5.73)	$	7.28
FTRs at Dec. 31, 2020	$	4,805	$	1,625	RTO auction pricing	FTR price - per MWh	$	(3.49)	$	4.36

Cleco Power
	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW		HIGH
FTRs at June 30, 2021	$	6,867	$	877	RTO auction pricing	FTR price - per MWh	$	(2.03)	$	7.28
FTRs at Dec. 31, 2020	$	4,337	$	1,121	RTO auction pricing	FTR price - per MWh	$	(3.34)	$	4.36

At June 30, 2021, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents and restricted cash equivalents. The following tables present the institutional money market funds in cash and cash equivalents and restricted cash and cash equivalents as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021, and December 31, 2020:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Cash and cash equivalents	$	73,412	$	80,712
Current restricted cash and cash equivalents	$	2,949	$	4,545
Non-current restricted cash and cash equivalents	$	744	$	744

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Cash and cash equivalents	$	16,112	$	20,812
Current restricted cash and cash equivalents	$	2,949	$	4,545

Institutional money market fund assets are discounted to the current period using a published U.S. Treasury interest rate as a proxy for a risk-free rate of return. If the money market funds failed to perform under the terms of the investments, Cleco and Cleco Power would be exposed to a loss of the invested amounts. Collateral on these types of investments is not required by either Cleco or Cleco Power. The Level 2 institutional money market funds asset consists of a single class. In order to capture interest income and minimize risk, cash is invested in money market funds that invest primarily in

short-term securities issued by the U.S. Treasury to maintain liquidity and achieve the goal of a net asset value of a dollar. The risks associated with this class are counterparty risk of the fund manager and risk of price volatility associated with the underlying securities of the fund.

Derivatives and other commodity contracts that do not qualify for derivative accounting treatment transacted directly with a counterparty and are not cleared on an exchange contain counterparty credit risk. Cleco may be required to provide credit support or pay liquidated damages with respect to any open trading contracts that Cleco has entered into or may enter into in the future. The amount of credit support that Cleco may be required to provide at any point in the future is dependent on the amount of the initial contract, changes in the market price, changes in open contracts, and changes in the amounts counterparties owe to Cleco. Changes in any of these factors could cause the amount of requested credit support to increase or decrease.

Cleco Power and Cleco Cajun’s FTRs are valued using MISO’s monthly auction prices. Forward seasonal periods are not included in every monthly auction; therefore, the average of the most recent seasonal auction prices is used for monthly valuation. FTRs are categorized as Level 3 fair value measurements because the only relevant value available comes from MISO auctions, which occur monthly in the Multi-Period Monthly Auction.

During the six months ended June 30, 2021, and the year ended December 31, 2020, Cleco did not experience any transfers between levels within the fair value hierarchy.

Commodity Contracts

The following tables present the fair values of derivative instruments and their respective line items as recorded on

Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021, and December 31, 2020:

Cleco
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2021		AT DEC. 31, 2020
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	8,662	$	4,805
Current	Energy risk management liabilities	(1,161)		(1,625)
Other commodity derivatives
Current	Energy risk management assets	30,063		8,276
Non-current	Other deferred charges	25,771		323
Current	Energy risk management liabilities	—		(828)
Non-current	Other deferred credits	—		(784)
Commodity-related contracts, net		$	63,335	$	10,167

Cleco Power
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2021		AT DEC. 31, 2020
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	6,867	$	4,337
Current	Energy risk management liabilities	(877)		(1,121)
Commodity-related contracts, net		$	5,990	$	3,216

The following tables present the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2021, and 2020:

Cleco
	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	INCOME STATEMENT LINE ITEM	2021		2020		2021		2020
Commodity-related contracts
FTRs(1)	Electric operations	$	1,763	$	1,852	$	9,207	$	3,248
FTRs(1)	Purchased power	702		92		(7,858)		(289)
Other commodity derivatives	Fuel used for electric generation	(51,683)		9,316		(57,897)		2,208
Total		$	(49,218)	$	11,260	$	(56,548)	$	5,167

(1) For the three and six months ended June 30, 2021, unrealized losses associated with FTRs for Cleco Power of $0.4 million were reported through Accumulated deferred fuel on the balance sheet. For the three and six months ended June 30, 2020, unrealized losses associated with FTRs for Cleco Power of $1.3 million were reported through Accumulated deferred fuel on the balance sheet.

Cleco Power
	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	INCOME STATEMENT LINE ITEM	2021		2020		2021		2020
Commodity-related contracts
FTRs(1)	Electric operations	$	1,763	$	1,852	$	9,208	$	3,249
FTRs(1)	Purchased power	(1,233)		(1,319)		(8,414)		(2,070)
Total		$	530	$	533	$	794	$	1,179

(1) For the three and six months ended June 30, 2021, unrealized losses associated with FTRs of $0.4 million were reported through Accumulated deferred fuel on the balance sheet. For the three and six months ended June 30, 2020, unrealized losses associated with FTRs of $1.3 million were reported through Accumulated deferred fuel on the balance sheet.

The total volume of FTRs that Cleco Power had outstanding at June 30, 2021, and December 31, 2020, was 19.8 million MWh and 9.5 million MWh, respectively. The total volume of FTRs that Cleco had outstanding at June 30, 2021, and December 31, 2020, was 30.9 million MWh and 15.3 million MWh, respectively. The total volume of other commodity derivatives Cleco had outstanding at June 30, 2021, and December 31, 2020, was 127.9 million MMBtus and 73.0 million MMBtus, respectively.

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Debt

6 Months Ended

Jun. 30, 2021

Debt Disclosure [Abstract]

Debt

Note 7 — Debt

On May 21, 2021, Cleco Holdings entered into a $175.0 million revolving credit agreement and a $266.0 million term loan agreement. These agreements replaced Cleco Holdings’ existing revolving credit agreement and term loan agreement. The revolving credit agreement matures on May 21, 2026. Under this agreement, Cleco Holdings is required to maintain total indebtedness less than or equal to 65% of total

capitalization. The borrowing costs under this agreement are currently equal to LIBOR plus 1.625% or ABR plus 0.625%, plus commitment fees of 0.275%. If Cleco Holdings’ credit ratings were to be downgraded one level by the credit rating agencies, Cleco Holdings may be required to pay higher commitment fees and additional interest of 0.175%. At June 30, 2021, Cleco Holdings had no borrowings outstanding under its revolving credit agreement. Cleco Holdings’ term loan agreement matures on May 21, 2024 and has an interest rate of LIBOR plus 1.625% or ABR plus 0.625%.

In addition, on May 21, 2021, Cleco Power entered into a $300.0 million revolving credit agreement and a $125.0 million term loan agreement. These agreements replaced Cleco Power’s existing revolving credit agreement and term loan agreement. The revolving credit agreement matures on May 21, 2026. Under this agreement, Cleco Power is required to maintain total indebtedness less than or equal to 65% of total capitalization. The borrowing costs under this agreement are currently equal to LIBOR plus 1.25% or ABR plus 0.25%, plus

commitment fees of 0.15%. If Cleco Power’s credit ratings were to be downgraded one level by the credit rating agencies, Cleco Power may be required to pay higher commitment fees and additional interest of 0.15%. At June 30, 2021, Cleco Power had $160.0 million of borrowings outstanding under the revolving credit agreement. Cleco Power’s term loan agreement matures on May 21, 2024 and has an interest rate of LIBOR plus 1.25% or ABR plus 0.25%.

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Pension Plan and Employee Benefits

6 Months Ended

Jun. 30, 2021

Retirement Benefits [Abstract]

Pension Plan and Employee Benefits

Note 8 — Pension Plan and Employee Benefits

Pension Plan and Other Benefits Plan

Employees hired before August 1, 2007, are covered by a non-contributory, defined benefit pension plan. Based on the funding assumptions at December 31, 2020, and the funding relief provided by the American Rescue Plan Act, which was signed by the President on March 11, 2021, management

estimates that no pension contributions will be required through 2025. As of June 30, 2021, Cleco expects to make $67.0 million in discretionary contributions to the pension plan in 2021, which would offset future required contributions.

Cleco Power is the plan sponsor and Support Group is the plan administrator. Benefits under the plan reflect an employee’s years of service, age at retirement, and accrued benefit at retirement.

Cleco’s retirees may be eligible to receive Other Benefits. Dependents of Cleco’s retirees may also be eligible to receive Other Benefits with the exception of life insurance benefits.

The non-service components of net periodic pension and Other Benefits cost are included in Other income (expense), net within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. The components of net periodic pension and Other Benefits cost for the three and six months ended June 30, 2021, and 2020 were as follows:

	PENSION BENEFITS				OTHER BENEFITS
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	2,730	$	2,582	$	595	$	508
Interest cost	4,719		5,278		323		410
Expected return on plan assets	(5,698)		(6,242)		—		—
Amortizations
Prior period service credit	—		(15)		—		—
Net loss	5,607		4,477		384		340
Net periodic benefit cost	$	7,358	$	6,080	$	1,302	$	1,258

	PENSION BENEFITS				OTHER BENEFITS
	FOR THE SIX MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	5,258	$	4,910	$	1,190	$	1,015
Interest cost	9,334		10,408		645		820
Expected return on plan assets	(11,400)		(12,487)		—		—
Amortizations
Prior period service credit	—		(30)		—		—
Net loss	10,369		8,149		770		680
Net periodic benefit cost	$	13,561	$	10,950	$	2,605	$	2,515

Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2021, was $0.9 million and $1.8 million, respectively. The expense of the pension plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2020, was $1.3 million and $1.7 million, respectively.

Cleco Holdings is the plan sponsor for the other benefit plans. There are no assets set aside in a trust, and the liabilities are reported on the individual subsidiaries’ financial statements. The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2021, was $1.2 million and $2.4 million, respectively. The expense related to other benefits reflected in Cleco Power’s Condensed

Consolidated Statements of Income for the three and six months ended June 30, 2020, was $1.2 million and $2.5 million, respectively. The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at June 30, 2021, and December 31, 2020, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	4,463	$	4,463
Non-current	$	51,522	$	51,868

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	3,865	$	3,865
Non-current	$	40,449	$	40,734

SERP

Certain Cleco officers are covered by SERP. Cleco does not fund the SERP liability, but instead pays for current benefits out of general funds available. Cleco Power has formed a rabbi trust. The life insurance policies issued on SERP participants designate the rabbi trust as the beneficiary. Market conditions could have a significant impact on the cash surrender value of the life insurance policies. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ death benefits, as well as future SERP payments. However, because SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. All SERP benefits are paid out of general cash available of the respective companies that employed the officer. Cleco Power is the plan sponsor and Support Group is the plan administrator.

The non-service components of net periodic benefit cost related to SERP are included in Other income (expense), net within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. The components of the net periodic benefit cost related to SERP for the three and six months ended June 30, 2021, and 2020 were as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	61	$	105	$	116	$	200
Interest cost	644		734		1,269		1,466
Amortizations
Prior period service credit	(55)		(67)		(107)		(107)
Net (gain) loss	(401)		835		613		1,592
Net periodic benefit cost	$	249	$	1,607	$	1,891	$	3,151

The expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2021, was less than $0.1 million and $0.3 million, respectively. The expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2020, was $0.2 million and $0.5 million, respectively.

Liabilities relating to SERP are reported on the individual subsidiaries’ financial statements. The current and non-current portions of the SERP liability for Cleco and Cleco Power at June 30, 2021, and December 31, 2020, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	4,703	$	4,703
Non-current	$	91,355	$	92,522

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	711	$	711
Non-current	$	19,364	$	19,828

401(k) Plan

Cleco’s 401(k) Plan is intended to provide active, eligible employees with voluntary, long-term savings and investment opportunities. The 401(k) Plan is a defined contribution plan and is subject to the applicable provisions of the Employee

Retirement Income Security Act of 1974. In accordance with the 401(k) Plan, employer contributions are made in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Participation in the Plan is voluntary, and active Cleco employees are eligible to participate. Cleco’s 401(k) Plan expense for the three and six months ended June 30, 2021, and 2020 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
401(k) Plan expense	$	2,120	$	1,898	$	4,880	$	5,154

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2021, and 2020 was as follows:

	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
401(k) Plan expense	$	946	$	832	$	2,326	$	2,495

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Income Taxes

6 Months Ended

Jun. 30, 2021

Income Tax Disclosure [Abstract]

Income Taxes

Note 9 — Income Taxes

Effective Tax Rates

The following tables summarize the effective income tax rates for Cleco and Cleco Power for the three and six months ended June 30, 2021, and 2020:

Cleco
	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30
	2021		2020		2021		2020
Effective tax rate	11.1	%	23.9	%	0.4	%	23.4	%

Cleco Power
	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2021		2020		2021		2020
Effective tax rate	24.6	%	24.9	%	(1.7)	%	24.1	%

For the three and six months ended June 30, 2021, the effective income tax rates for both Cleco and Cleco Power were different than the federal statutory rate primarily due to the amortization of excess ADIT, adjustment to record tax expense at the projected annual effective tax rate, and state tax expense.

For the three and six months ended June 30, 2020, the effective income tax rates for both Cleco and Cleco Power were different than the federal statutory rate primarily due to the adjustment to record tax expense at the projected annual effective tax rate; the flow through of tax benefits, including AFUDC equity; and state tax expense.

Uncertain Tax Positions

Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. At June 30, 2021, and December 31, 2020, Cleco and Cleco Power had no liability for uncertain tax positions or interest payable related to uncertain tax positions. Cleco estimates that it is

reasonably possible that the balance of unrecognized tax benefits as of June 30, 2021, for Cleco and Cleco Power would be unchanged in the next 12 months. The settlement of open tax years could involve the payment of additional taxes, and/or the recognition of tax benefits, which may have an effect on Cleco’s effective tax rate.

Income Tax Audits

Cleco participates in the IRS’s Compliance Assurance Process in which tax positions are examined and agreed upon prior to filing the federal tax return. While the statute of limitations remains open for tax years 2017, 2018, and 2019, the IRS has completed its review of years 2017 through 2019, and these tax returns were filed consistent with the IRS’s review. The IRS has placed Cleco in the Bridge phase of the Compliance Assurance Process for the 2020 tax year. In this phase, the IRS will not accept any disclosures, conduct any reviews, or provide any assurances.

The state income tax years 2017, 2018, and 2019 remain open to examination by the Louisiana Department of Revenue.

Cleco classifies income tax penalties as a component of other expense. For the three and six months ended June 30, 2021, and 2020, no penalties were recognized.

CARES Act

In March 2020, the CARES Act was signed into law. The CARES Act includes tax relief provisions such as an alternative minimum tax credit refund, a five-year net operating loss carryback from years 2018 through 2020, and deferred payments of employer payroll taxes.

Cleco deferred $6.0 million in employer payroll tax payments for the period March 27, 2020, through December 31, 2020. Cleco will pay $3.0 million of the obligation by December 31, 2021, and the remaining $3.0 million by December 31, 2022.

Cleco Power deferred $3.6 million in employer payroll tax payments for the period March 27, 2020, through December 31, 2020. Cleco Power will pay $1.8 million of the obligation by December 31, 2021, and the remaining $1.8 million by December 31, 2022.

The CARES Act also includes modifications on the limitations of business interest for the 2019 and 2020 tax years. The modifications increase the allowable business interest deduction from 30% to 50% of adjusted taxable income. Cleco does not anticipate having any disallowed interest for the 2020 tax year.

Consolidated Appropriations Act of 2021

In December 2020, the Consolidated Appropriations Act of 2021 (CAA) was signed into law. The CAA includes COVID-19 tax relief and tax extender provisions including extensions of time to begin construction on and placed in-service assets generating production tax credits and income tax credits, 100% deductibility of business meals in 2021 and 2022, and an extension of the work opportunity tax credit. The income tax

credit percentage has been increased for projects starting construction through 2023 and placed in service by the end of 2025. Management does not expect the CAA to have a material impact on the Registrants.

American Jobs Act of 2021

On March 31, 2021, the President announced the American Jobs Act. This proposal includes a number of incentives to encourage construction of certain transmission and energy storage property. The proposed act also proposes to raise the federal statutory corporate income tax rate from 21% to 28% and to introduce a minimum tax based on book income. Currently, management is unable to predict the impact of the proposed act on the Registrants.

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Disclosures about Segments

6 Months Ended

Jun. 30, 2021

Segment Reporting [Abstract]

Disclosures about Segments

Note 10 — Disclosures about Segments

Cleco’s reportable segments are based on its method of internal reporting, which disaggregates business units by its first-tier subsidiary. Cleco’s reportable segments are Cleco Power and Cleco Cajun.

Each reportable segment engages in business activities from which it earns revenue and incurs expenses. Segment managers report periodically to Cleco’s CEO, who is Cleco’s chief operating decision maker, with discrete financial information and, at least quarterly, present discrete financial information to Cleco and, in the case of Cleco Power, Cleco Power’s Boards of Managers. The reportable segment prepares budgets that are presented to and approved by Cleco and, in the case of Cleco Power, Cleco Power’s Boards of Managers. The column shown as Other in the following tables includes the holding company, a shared services subsidiary, and an investment subsidiary. There were no changes to Cleco’s existing reportable segments.

The financial results in the following tables are presented on an accrual basis. EBITDA is a key non-GAAP financial measure used by the CEO to assess the operating performance of Cleco’s segments. Management evaluates the performance of Cleco’s segments and allocates resources to them based on segment profit and the requirements to implement strategic initiatives and projects to meet current business objectives. EBITDA is defined as net income adjusted for interest, income taxes, depreciation, and amortization. Depreciation and amortization in the following tables includes amortization of intangible assets and liabilities recorded for the fair value adjustment of wholesale power supply agreements as a result of the 2016 Merger and the Cleco Cajun Transaction, as well as amortization of deferred lease revenue resulting from the Cleco Cajun Transaction. Material intercompany transactions occur on a regular basis. These intercompany transactions relate primarily to joint and common administrative support services as well as transmission services provided by Cleco Power to Cleco Cajun.

Segment Information for the Three Months Ended June 30,
2021 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	262,948	$	91,407		$	354,355
Other operations	16,269		30,655			46,924
Affiliate revenue	1,224		—			1,224
Electric customer credits	(18,762)		244			(18,518)
Operating revenue, net	$	261,679	$	122,306		$	383,985
Net income	$	27,421	$	52,494		$	79,915
Add: Depreciation and amortization	40,933		12,339		(1)	53,272
Less: Interest income	825		3			828
Add: Interest charges	18,237		(180)			18,057
Add: Federal and state income tax expense	8,956		18,063			27,019
EBITDA	$	94,722	$	82,713		$	177,435
(1) Includes $3.3 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(2.3) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2021 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	354,355	$	(2,420)		$	1	$	351,936
Other operations	46,924		1			(1,595)		45,330
Affiliate revenue	1,224		26,120			(27,344)		—
Electric customer credits	(18,518)		—			1		(18,517)
Operating revenue, net	$	383,985	$	23,701		$	(28,937)	$	378,749
Depreciation and amortization	$	53,272	$	4,427	(1)	$	—	$	57,699
Interest income	$	828	$	14		$	(13)	$	829
Interest charges	$	18,057	$	15,248		$	(14)	$	33,291
Federal and state income tax (benefit)	$	27,019	$	(17,182)		$	—	$	9,837
Net income (loss)	$	79,915	$	(1,093)		$	—	$	78,822
(1) Includes $2.4 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

2020 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	239,643	$	84,733		$	324,376
Other operations	15,904		30,636			46,540
Affiliate revenue	1,240		43			1,283
Electric customer credits	(9,100)		—			(9,100)
Operating revenue, net	$	247,687	$	115,412		$	363,099
Net income	$	28,233	$	26,762		$	54,995
Add: Depreciation and amortization	41,596		11,143		(1)	52,739
Less: Interest income	755		103			858
Add: Interest charges	18,603		120			18,723
Add: Federal and state income tax expense	9,356		8,601			17,957
EBITDA	$	97,033	$	46,523		$	143,556
(1) Includes $3.1 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(2.3) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2020 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	324,376	$	(2,420)		$	—	$	321,956
Other operations	46,540		1			(1,639)		44,902
Affiliate revenue	1,283		29,138			(30,421)		—
Electric customer credits	(9,100)		—			—		(9,100)
Operating revenue, net	$	363,099	$	26,719		$	(32,060)	$	357,758
Depreciation and amortization	$	52,739	$	4,565	(1)	$	—	$	57,304
Interest income	$	858	$	55		$	(15)	$	898
Interest charges	$	18,723	$	16,007		$	(15)	$	34,715
Federal and state income tax expense (benefit)	$	17,957	$	(4,364)		$	—	$	13,593
Net income (loss)	$	54,995	$	(11,826)		$	(1)	$	43,168
(1) Includes $2.4 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

Segment Information for the Six Months Ended June 30,
2021 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	530,107	$	192,914		$	723,021
Other operations	34,895		63,694			98,589
Affiliate revenue	2,879		—			2,879
Electric customer credits	(39,738)		244			(39,494)
Operating revenue, net	$	528,143	$	256,852		$	784,995
Net income	$	45,846	$	66,975		$	112,821
Add: Depreciation and amortization	83,009		23,991		(2)	107,000
Less: Interest income	1,468		6			1,474
Add: Interest charges	36,883		(332)			36,551
Add: Federal and state income tax (benefit) expense	(767)		22,673			21,906
EBITDA	$	163,503	$	113,301		$	276,804
Additions to property, plant, and equipment	$	134,185	$	4,882		$	139,067
Equity investment in investees (1)	$	5,572	$	—		$	5,572
Goodwill (1)	$	1,490,797	$	—		$	1,490,797
Total segment assets (1)	$	6,438,218	$	1,078,534		$	7,516,752
(1) Balances as of June 30, 2021. (2) Includes $6.4 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(4.6) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2021 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	723,021	$	(4,840)		$	—	$	718,181
Other operations	98,589		2			(3,535)		95,056
Affiliate revenue	2,879		53,276			(56,155)		—
Electric customer credits	(39,494)		—			—		(39,494)
Operating revenue, net	$	784,995	$	48,438		$	(59,690)	$	773,743
Depreciation and amortization	$	107,000	$	8,862	(2)	$	—	$	115,862
Interest income	$	1,474	$	57		$	(56)	$	1,475
Interest charges	$	36,551	$	30,687		$	(55)	$	67,183
Federal and state income tax expense (benefit)	$	21,906	$	(21,490)		$	—	$	416
Net income (loss)	$	112,821	$	(13,672)		$	—	$	99,149
Additions to property, plant, and equipment	$	139,067	$	1,440		$	—	$	140,507
Equity investment in investees (1)	$	5,572	$	—		$	—	$	5,572
Goodwill (1)	$	1,490,797	$	—		$	—	$	1,490,797
Total segment assets (1)	$	7,516,752	$	569,126		$	(144,409)	$	7,941,469
(1) Balances as of June 30, 2021. (2) Includes $4.8 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

2020 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	464,073	$	173,880		$	637,953
Other operations	31,668		61,597			93,265
Affiliate revenue	2,346		204			2,550
Electric customer credits	(17,440)		(153)			(17,593)
Operating revenue, net	$	480,647	$	235,528		$	716,175
Net income	$	40,064	$	46,298		$	86,362
Add: Depreciation and amortization	85,273		22,041		(2)	107,314
Less: Interest income	1,709		258			1,967
Add: Interest charges	37,184		131			37,315
Add: Federal and state income tax expense	12,694		15,022			27,716
EBITDA	$	173,506	$	83,234		$	256,740
Additions to property, plant, and equipment	$	132,578	$	5,417		$	137,995
Equity investment in investees (1)	$	9,072	$	—		$	9,072
Goodwill (1)	$	1,490,797	$	—		$	1,490,797
Total segment assets (1)	$	6,256,944	$	1,029,812		$	7,286,756
(1) Balances as of December 31, 2020. (2) Includes $6.2 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(4.6) million deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2020 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	637,953	$	(4,840)		$	—	$	633,113
Other operations	93,265		1			(3,456)		89,810
Affiliate revenue	2,550		58,415			(60,965)		—
Electric customer credits	(17,593)		—			—		(17,593)
Operating revenue, net	$	716,175	$	53,576		$	(64,421)	$	705,330
Depreciation and amortization	$	107,314	$	9,079	(2)	$	—	$	116,393
Interest income	$	1,967	$	155		$	(68)	$	2,054
Interest charges	$	37,315	$	32,617		$	(69)	$	69,863
Federal and state income tax expense (benefit)	$	27,716	$	(12,561)		$	—	$	15,155
Net income (loss)	$	86,362	$	(36,865)		$	(1)	$	49,496
Additions to property, plant, and equipment	$	137,995	$	1,344		$	—	$	139,339
Equity investment in investees (1)	$	9,072	$	—		$	—	$	9,072
Goodwill (1)	$	1,490,797	$	—		$	—	$	1,490,797
Total segment assets (1)	$	7,286,756	$	595,217		$	(156,404)	$	7,725,569
(1) Balances as of December 31, 2020. (2) Includes $4.8 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Net income	$	78,822	$	43,168	$	99,149	$	49,496
Add: Depreciation and amortization	57,699		57,304		115,862		116,393
Less: Interest income	829		898		1,475		2,054
Add: Interest charges	33,291		34,715		67,183		69,863
Add: Federal and state income tax expense	9,837		13,593		416		15,155
Add: Other corporate costs and noncash items (1)	(1,385)		(4,326)		(4,331)		7,887
Total segment EBITDA	$	177,435	$	143,556	$	276,804	$	256,740
(1) Adjustments made for Other and Elimination totals not allocated to total segment EBITDA.

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Regulation and Rates

6 Months Ended

Jun. 30, 2021

Regulated Operations [Abstract]

Regulation and Rates

Note 11 — Regulation and Rates

Provision for rate refund on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets consisted primarily of the following:

(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
FRP	$	2,392	$	1,786
TCJA	$	2,057	$	2,057
Cleco Katrina/Rita storm recovery charges	$	1,610	$	1,617
Site-specific industrial customer	$	990	$	710
Transmission ROE	$	250	$	595
FERC audit	$	—	$	1,912

FRP

Prior to July 1, 2021, Cleco Power’s annual retail earnings were subject to an FRP established by the LPSC in June 2014. The 2014 FRP allowed Cleco Power to earn a target ROE of 10.0%, while providing the opportunity to earn up to 10.9%. Additionally, 60.0% of retail earnings between 10.9% and 11.75%, and all retail earnings over 11.75%, were required to be refunded to customers. In June 2019, Cleco Power filed an application with the LPSC for a new FRP. The FRP rates previously established remained in effect due to delays in the base rate case. On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan. Effective July 1, 2021, under the terms of the new FRP, Cleco Power is allowed to earn a target ROE of 9.5%, while providing the opportunity to earn up to 10.0%. Additionally, 60.0% of retail earnings between 10.0% and 10.5%, and all retail earnings over 10.5%, are required to be refunded to customers. The amount of credits due to customers, if any, is determined by Cleco Power and the LPSC annually. Cleco Power’s next base rate case is required to be filed with the LPSC on or before March 31, 2023.

Cleco Power filed its monitoring report for the 12 months ended June 30, 2019, on October 31, 2019, indicating that no refund was due. On June 30, 2021, the LPSC Staff filed their report indicating agreement with Cleco Power’s refund calculation for the 12 months ending June 30, 2019. Cleco Power anticipates approval of the report from the LPSC in the third quarter of 2021. Monitoring reports for the 12 months ended June 30, 2020, and 2021 were not required due to the expiration of the 2014 FRP. The next monitoring report will be filed on or before October 31, 2022, for the 12 months ending June 30, 2022.

Cleco Power continued to accrue the annual cost of service savings resulting from the 2016 Merger Commitments through June 30, 2021. Beginning July 1, 2021, the annual cost of service savings are included in Cleco Power’s new retail rate plan. At June 30, 2021, Cleco Power had $2.4 million accrued for the period July 1, 2019, through June 30, 2021. Cleco Power expects to refund its customers $1.2 million in September 2021 and September 2022.

TCJA

The provisions of the TCJA reduced the top federal statutory corporate income tax rate from 35% to 21%. As a result of the tax rate reduction, on January 1, 2018, Cleco Power began accruing an estimated reserve for the reduction in the federal statutory corporate income tax rate. In February 2018, the LPSC directed utilities, including Cleco Power, to provide considerations of the appropriate manner to flow through to ratepayers the benefits of the reduction in corporate income

taxes as a result of the TCJA. In July 2019, the LPSC approved Cleco Power’s rate refund of $79.2 million, plus interest, for the reduction in the statutory federal tax rate for the period from January 2018 to June 2020. The refund was credited to customers over 12 months beginning August 1, 2019.

In July 2019, the LPSC approved Cleco Power’s motion to address the rate redesign and the regulatory liability for excess ADIT, resulting from the enactment of the TCJA, in Cleco Power’s current base rate case.

As a result of the delay in the rate case, on July 15, 2020, the LPSC approved Cleco Power’s application to extend the TCJA bill credits at the same rate as determined in the initial TCJA refund of approximately $7.0 million per month. The extension was for the period of August 2020 through November 2020. On November 13, 2020, Cleco Power again received approval for its application to extend the TCJA bill credits from November 30, 2020, until such a time that the rate case was completed. The $7.0 million monthly refund consisted of approximately $4.4 million, which was to be funded by the unprotected excess ADIT, and approximately $2.6 million, which is the change in the federal statutory corporate income tax rate from 35% to 21%. At June 30, 2021, Cleco Power had $2.1 million accrued for the estimated federal tax-related benefits from the TCJA.

On June 16, 2021, the LPSC approved Cleco Power’s new retail rate plan which includes the settlement of the TCJA protected and unprotected excess ADIT. Effective July 1, 2021, all retail customers will continue receiving bill credits resulting from the TCJA. The target retail portion of the unprotected excess ADIT is approximately $2.5 million monthly and will be credited over a period of three years concluding on June 30, 2024. The retail portion of the protected excess ADIT will be credited until the full amount of the protected excess ADIT has been returned to Cleco Power’s customers through bill credits. At June 30, 2021, Cleco Power had $324.6 million accrued for the excess ADIT, of which $39.5 million is reflected in current regulatory liabilities.

Cleco Katrina/Rita Storm Recovery Charges

Prior to the repayment of the storm recovery bonds in March 2020, Cleco Katrina/Rita had the right to bill and collect storm restoration costs from Cleco Power’s customers to pay administrative fees, interest, and principal on the Cleco Katrina/Rita storm recovery bonds. Amounts remaining after the final principal and interest payments on the storm recovery bonds and payments for final administrative and winding up activities are subject to refund. At June 30, 2021, Cleco Power had $1.6 million accrued for Cleco Katrina/Rita storm recovery charges that are subject to refund. For more information on Cleco Katrina/Rita’s restricted cash, see Note 1 — “Summary of Significant Accounting Policies — Restricted Cash and Cash Equivalents.”

Transmission ROE

Two complaints were filed with FERC seeking to reduce the ROE component of the transmission rates that MISO transmission owners, including Cleco Power, may collect under the MISO tariff. As of June 30, 2021, Cleco Power had $0.3 million accrued for the change in ROE. For more information on the ROE complaints, see Note 13 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — Transmission ROE.”

FERC Audit

As of June 30, 2021, the estimated refund was fully refunded to Cleco Power’s wholesale transmission customers as a combination of refund payments and a reduction in Attachment O of the MISO tariff and grandfathered agreement rates over the preceding 12 months. For more information about the FERC audit, see Note 13 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — FERC Audit.”

SSR

In September 2016, Cleco Power filed an Attachment Y with MISO requesting retirement of Teche Unit 3 effective April 1, 2017. MISO conducted a study which determined the proposed retirement of Teche Unit 3 would result in violations of specific applicable reliability standards for which no mitigation is available. As a result, MISO designated Teche Unit 3 as an SSR unit until such time that an appropriate alternative solution could be implemented to mitigate reliability issues. One mitigating factor identified was Cleco Power’s Terrebonne to Bayou Vista Transmission project, which was completed in April 2019. Cleco Power received a termination notice, effective April 30, 2019, and filed paperwork to withdraw the filed Attachment Y. While operating as an SSR unit, Cleco Power received monthly payments that included recovery of expenses, including capital expenditures, related to the operations of Teche Unit 3. Additionally, MISO allocated SSR costs to the load serving entities that required the operation of the SSR unit, including Cleco Power. These payments and cost allocations were finalized as part of a MISO SSR settlement approved in December 2018. Cleco Power operated Teche Unit 3 as an SSR unit from April 2017 until April 2019.

Cleco Power expects Teche Unit 3 to continue to be available to run and to continue to offer the unit into MISO through 2024, barring a significant unit failure. At June 30, 2021, Cleco Power had $4.3 million accrued for the net capital refund for capital expenditures paid for by third parties while operating under the SSR agreement. The capital refund is expected to be paid in early 2022.

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Variable Interest Entities

6 Months Ended

Jun. 30, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Variable Interest Entities

Note 12 — Variable Interest Entities

Cleco and Cleco Power apply the equity method of accounting to report the investment in Oxbow in the consolidated financial statements. Under the equity method, the assets and liabilities of this entity are reported as Equity investment in investee on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of this entity are netted and reported as equity income or loss from investees on Cleco and Cleco Power’s Condensed Consolidated Statements of Income.

Oxbow is owned 50% by Cleco Power and 50% by SWEPCO. Cleco Power is not the primary beneficiary because it shares the power to control Oxbow’s significant activities with SWEPCO. Cleco Power’s current assessment of its maximum exposure to loss related to Oxbow at June 30, 2021, consisted of its equity investment of $5.6 million. During the six months ended June 30, 2021, Cleco Power had a return of equity investment from Oxbow of $3.5 million.

The following table presents the components of Cleco Power’s equity investment in Oxbow:

INCEPTION TO DATE (THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Purchase price	$	12,873	$	12,873
Cash contributions	6,399		6,399
Distributions	(13,700)		(10,200)
Total equity investment in investee	$	5,572	$	9,072

The following table compares the carrying amount of Oxbow’s assets and liabilities with Cleco Power’s maximum exposure to loss related to its investment in Oxbow:

(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Oxbow’s net assets/liabilities	$	11,145	$	18,145
Cleco Power’s 50% equity	$	5,572	$	9,072
Cleco Power’s maximum exposure to loss	$	5,572	$	9,072

The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Operating revenue	$	1,627	$	29,110	$	3,626	$	30,991
Operating expenses	1,627		29,110		3,626		30,991
Income before taxes	$	—	$	—	$	—	$	—

Prior to June 30, 2020, DHLC mined lignite reserves at Oxbow through the Amended Lignite Mining Agreement. The lignite reserves were intended to be used to provide fuel to the Dolet Hills Power Station. Under the Amended Lignite Mining Agreement, DHLC bills Cleco Power its proportionate share of incurred lignite extraction and associated mining-related costs. Oxbow bills Cleco Power its proportionate share of incurred costs related to mineral rights and land leases. For more information on DHLC and the Oxbow mine, see Note 13 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Risks and Uncertainties.”

Oxbow has no third-party agreements, guarantees, or other third-party commitments that contain obligations affecting Cleco Power’s investment in Oxbow.

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees

6 Months Ended

Jun. 30, 2021

Commitments and Contingencies Disclosure [Abstract]

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees

Note 13 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees

Litigation

2016 Merger

In connection with the 2016 Merger, four actions were filed in the Ninth Judicial District Court for Rapides Parish, Louisiana and three actions were filed in the Civil District Court for Orleans Parish, Louisiana. The petitions in each action generally alleged, among other things, that the members of Cleco Corporation’s Board of Directors breached their fiduciary duties by, among other things, conducting an allegedly inadequate sale process, agreeing to the 2016 Merger at a price that allegedly undervalued Cleco, and failing to disclose material information about the 2016 Merger. The petitions also alleged that Como 1, Cleco Corporation, Merger Sub, and, in some cases, certain of the investors in Como 1 either aided and abetted or entered into a civil conspiracy to

advance those supposed breaches of duty. The petitions sought various remedies, including monetary damages, which includes attorneys’ fees and expenses.

The four actions filed in the Ninth Judicial District Court for Rapides Parish are captioned as follows:

•Braunstein v. Cleco Corporation, No. 251,383B (filed October 27, 2014),

•Moore v. Macquarie Infrastructure and Real Assets, No. 251,417C (filed October 30, 2014),

•Trahan v. Williamson, No. 251,456C (filed November 5, 2014), and

•L’Herisson v. Macquarie Infrastructure and Real Assets, No. 251,515F (filed November 14, 2014).

In November 2014, the plaintiff in the Braunstein action moved for a dismissal of the action without prejudice, and that motion was granted in November 2014. In December 2014, the Court consolidated the remaining three actions and appointed interim co-lead counsel, and dismissed the investors in Cleco Partners as defendants, per agreement of the parties. Also, in December 2014, the plaintiffs in the consolidated action filed a Consolidated Amended Verified Derivative and Class Action Petition for Damages and Preliminary and Permanent Injunction.

The three actions filed in the Civil District Court for Orleans Parish were captioned as follows:

•Butler v. Cleco Corporation, No. 2014-10776 (filed November 7, 2014),

•Creative Life Services, Inc. v. Cleco Corporation, No. 2014-11098 (filed November 19, 2014), and

•Cashen v. Cleco Corporation, No. 2014-11236 (filed November 21, 2014). 

In December 2014, the directors and Cleco filed declinatory exceptions in each action on the basis that each action was improperly brought in Orleans Parish and should either be transferred to the Ninth Judicial District Court for Rapides Parish or dismissed. Also, in December 2014, the plaintiffs in each action jointly filed a motion to consolidate the three actions pending in Orleans Parish and to appoint interim co-lead plaintiffs and co-lead counsel. In January 2015, the Court in the Creative Life Services case sustained the defendants’ declinatory exceptions and dismissed the case so that it could be transferred to the Ninth Judicial District Court for Rapides Parish. In February 2015, the plaintiffs in Butler and Cashen also consented to the dismissal of their cases from Orleans Parish so they could be transferred to the Ninth Judicial District Court for Rapides Parish. By operation of the December 2014 order of the Ninth Judicial District Court for Rapides Parish, the Butler, Cashen, and Creative Life Services actions were consolidated into the actions pending in Rapides Parish.

In February 2015, the Ninth Judicial District Court for Rapides Parish held a hearing on a motion for preliminary injunction filed by plaintiffs in the consolidated action seeking to enjoin the shareholder vote for approval of the Merger Agreement. The District Court heard and denied the plaintiffs’ motion. In June 2015, the plaintiffs filed their Second Consolidated Amended Verified Derivative and Class Action Petition. Cleco filed exceptions seeking dismissal of the second amended petition in July 2015. The LPSC voted to

approve the 2016 Merger before the Court could consider the plaintiffs’ peremptory exceptions.

In March 2016 and May 2016, the plaintiffs filed their Third Consolidated Amended Verified Derivative Petition for Damages and Preliminary and Permanent Injunction and their Fourth Verified Consolidated Amended Class Action Petition, respectively. The fourth amended petition, which remains the operative petition and was filed after the 2016 Merger closed, eliminated the request for preliminary and permanent injunction and also named an additional executive officer as a defendant. The defendants filed exceptions seeking dismissal of the fourth amended Petition. In September 2016, the District Court granted the exceptions of no cause of action and no right of action and dismissed all claims asserted by the former shareholders. The plaintiffs appealed the District Court’s ruling to the Louisiana Third Circuit Court of Appeal. In December 2017, the Third Circuit Court of Appeal issued an order reversing and remanding the case to the District Court for further proceedings. In January 2018, Cleco filed a writ with the Louisiana Supreme Court seeking review of the Third Circuit Court of Appeal’s decision. The writ was denied in March 2018 and the parties are engaged in discovery in the District Court. In November 2018, Cleco filed renewed exceptions of no cause of action and res judicata, seeking to dismiss all claims. On December 21, 2018, the court dismissed Cleco Partners and Cleco Holdings as defendants per the agreement of the parties, leaving as the only remaining defendants certain former executive officers and independent directors. The District Court denied the defendants’ exceptions on January 14, 2019. A hearing on the plaintiffs’ motion for certification of a class was scheduled for August 26, 2019; however, prior to the hearing, the parties reached an agreement to certify a limited class. On September 7, 2019, the District Court certified a class limited to shareholders who voted against, abstained from voting, or did not vote on the 2016 Merger. Cleco believes that the allegations of the petitions in each action are without merit and that it has substantial meritorious defenses to the claims set forth in each of the petitions.

Gulf Coast Spinning

In September 2015, a potential customer sued Cleco for failure to fully perform an alleged verbal agreement to lend or otherwise fund its startup costs to the extent of $6.5 million. Gulf Coast Spinning Company, LLC (Gulf Coast), the primary plaintiff, alleges that Cleco promised to assist it in raising approximately $60.0 million, which Gulf Coast needed to construct a cotton spinning facility near Bunkie, Louisiana. According to the petition filed by Gulf Coast in the 12th Judicial District Court for Avoyelles Parish, Louisiana (the “District Court”), Cleco made such promises of funding assistance in order to cultivate a new industrial electric customer which would increase its revenues under a power supply agreement that it executed with Gulf Coast. Gulf Coast seeks unspecified damages arising from its inability to raise sufficient funds to complete the project, including lost profits.

Cleco filed an Exception of No Cause of Action arguing that the case should be dismissed. The District Court denied Cleco’s exception in December 2015, after considering briefs and arguments. In January 2016, Cleco appealed the District Court’s denial of its exception by filing with the Third Circuit Court of Appeal. In June 2016, the Third Circuit Court of Appeal denied the request to have the case dismissed. In July 2016, Cleco filed a writ to the Louisiana Supreme Court

seeking a review of the District Court’s denial of Cleco’s exception. In November 2016, the Louisiana Supreme Court denied Cleco’s writ application.

In February 2016, the parties agreed to a stay of all proceedings pending discussions concerning settlement. In May 2016, the District Court lifted the stay at the request of Gulf Coast. The parties are currently participating in discovery. Cleco believes the allegations of the petition are contradicted by the written documents executed by Gulf Coast, are otherwise without merit, and that it has substantial meritorious defenses to the claims alleged by Gulf Coast.

Dispute with Saulsbury Industries

In October 2018, Cleco Power sued Saulsbury Industries, Inc., the former general contractor for the St. Mary Clean Energy Center project, seeking damages for Saulsbury Industries, Inc.’s failure to complete the St. Mary Clean Energy Center project on time and for costs incurred by Cleco Power in hiring a replacement general contractor. The action was filed in the Ninth Judicial District Court for Rapides Parish, No. 263339. Saulsbury Industries, Inc. removed the case to the U.S. District Court for the Western District of Louisiana, on March 1, 2019. On September 14, 2020, Cabot Industries was allowed to join the case pending in the Ninth Judicial District Court for Rapides Parish.

In January 2019, Cleco Power was served with a summons in Saulsbury Industries, Inc. v. Cabot Corporation and Cleco Power LLC, in the U.S. District Court for the Western District of Louisiana. Saulsbury Industries, Inc. alleged that Cleco Power and Cabot Corporation caused delays in the St. Mary Clean Energy Center project, resulting in alleged impacts to Saulsbury Industries, Inc.’s direct and indirect costs. On June 5, 2019, Cleco Power and Cabot Corporation each filed separate motions to dismiss. On October 24, 2019, the District Court denied Cleco’s motion as premature and ruled that Saulsbury Industries, Inc. had six weeks to conduct discovery on specified jurisdictional issues. The Magistrate Judge presiding over the Western District of Louisiana consolidated cases issued a report and recommendation to the District Judge that the case instituted by Saulsbury Industries, Inc. be dismissed without prejudice and the case initiated by Cleco Power be remanded to the Ninth Judicial District Court for Rapides Parish. Saulsbury Industries, Inc. did not oppose the Magistrate Judge’s report and recommendation, and the District Judge issued a ruling that adopted the Magistrate Judge’s report and recommendation, which included reasoning consistent with Cleco Power’s arguments. Thus, the federal consolidated cases are now closed.

On October 10, 2019, Cleco Power was served with a summons in Saulsbury Industries, Inc. v. Cabot Corporation and Cleco Power LLC in the 16th Judicial District Court for St. Mary Parish, No. 133910-A. Saulsbury Industries, Inc. asserted the same claim as the Western District Litigation and further asserts claims for payment on an open account. On December 9, 2019, Cleco moved to stay the case, arguing that the Rapides Parish suit should proceed. On February 14, 2020, the court granted Cleco’s motion, which stay order remains in place until lifted. The 16th Judicial District Court for the St. Mary Parish case held a hearing on October 16, 2020, and the judge granted Cleco’s declinatory exceptions of lis pendens. Thus, the St. Mary’s Parish case has been dismissed. Saulsbury filed a motion for a new trial. The hearing on this motion was held on February 5, 2021, and the 16th Judicial District Court judge

denied Saulsbury’s motion for a new trial. Saulsbury has appealed this decision.

LPSC Audits

Fuel Audits

Generally, Cleco Power’s cost of fuel used for electric generation and the cost of purchased power are recovered through the LPSC-established FAC that enables Cleco Power to pass on to its customers substantially all such charges. Recovery of FAC costs is subject to periodic fuel audits by the LPSC. The LPSC FAC General Order issued in November 1997, in Docket No. U-21497 provides that an audit of FAC filings will be performed at least every other year. In March 2020, Cleco Power received a notice of audit from the LPSC for the period of January 2018 to December 2019. The total amount of fuel expense included in the audit is $565.8 million. Cleco Power has responded to several sets of data requests from the LPSC. Cleco Power has FAC filings for January 2020 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. Historically, the disallowances have not been material. If a disallowance of fuel cost is ordered resulting in a refund, any such refund could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.

On March 29, 2021, Cleco Power received approval from the LPSC to recover $50.0 million of incremental fuel and purchased power costs incurred as a result of Winter Storms Uri and Viola over a period of 12 months beginning in May 2021. On May 11, 2021, Cleco Power received notice of an audit from the LPSC for the fuel costs incurred during the time period required to restore services to Cleco Power’s customers during Winter Storms Uri and Viola. Management is unable to determine the outcome or timing of the audit. For more information on these winter storms, see Note 17 — “Storm Restoration — Winter Storms Uri and Viola.”

Environmental Audit

In 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides Cleco Power an EAC to recover from its customers certain costs of environmental compliance. The costs eligible for recovery are those for prudently incurred air emissions credits associated with complying with federal, state, and local air emission regulations that apply to the generation of electricity reduced by the sale of such allowances. Also eligible for recovery are variable emission mitigation costs, which are the costs of reagents such as ammonia and limestone that are a part of the fuel mix used to reduce air emissions, among other things. In March 2020, Cleco Power received notice from the LPSC of the EAC audit for the period of January 2018 to December 2019. The total amount of environmental expense included in the audit is $26.2 million. Cleco Power has responded to several sets of data requests from the LPSC. Cleco Power has EAC filings for January 2020 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. Historically, the disallowances have not been material. If a disallowance of environmental cost is ordered resulting in a refund to Cleco Power’s customers, any such refund could have a material adverse effect on the results

of operations, financial condition, or cash flows of the Registrants.

Cleco Power incurs environmental compliance expenses for reagents associated with the compliance standards of Mercury and Air Toxics Standards (MATS). These expenses are also eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC. In May 2020, the EPA finalized a rule that concluded that it is not appropriate and necessary to regulate hazardous air pollutants from coal- and oil-fired electric generating units. However, the EPA concluded that coal- and oil-fired electric generating units would not be removed from the list of regulated sources of hazardous air pollutants and would remain subject to MATS. The EPA also determined that the results of its risk and technology review did not require any revisions to the emissions standards. Several petitions for review of the rule’s findings were filed between May and July 2020 in the D.C. Circuit Court of Appeals. On January 20, 2021, the new Administration issued an executive order, which directs federal agency heads to review regulations and other actions over the past four years to determine if they are inconsistent with the policies announced in the executive order. The order specifically directs the EPA to consider issuing a proposed rule by August 2021 to suspend, revise, or rescind the rule. The EPA determined the most environmentally protective course is to implement the rules in the executive order. Management is unable to determine whether the outcome of the D.C. Circuit Court of Appeals review or the EPA’s review of the rule as a result of the executive order will result in changes to the MATS standards.

FERC Audit

Generally, Cleco Power records wholesale transmission revenue through approved formula rates, Attachment O of the MISO tariff and certain grandfathered agreements. The calculation of the rate formulas, as well as FERC accounting and reporting requirements, are subject to periodic audits by FERC. In March 2018, the Division of Audits and Accounting, within the Office of Enforcement of FERC, initiated an audit of Cleco Power for the period of January 1, 2014, through June 30, 2019. On September 27, 2019, Cleco Power received the final audit report, which indicated 12 findings of noncompliance with a combination of FERC accounting and reporting requirements and computation of revenue requirements along with 59 recommendations associated with the audit period. Cleco Power submitted a plan for implementing the audit recommendations on October 28, 2019. Cleco Power also submitted the refund analysis on November 7, 2019, which resulted in a refund related to the FERC audit findings, pending final assessment by the FERC Division of Audits and Accounting, which is expected in the third quarter of 2021. As of June 30, 2021, the estimated refund of $4.4 million was fully refunded to Cleco Power’s wholesale transmission customers as a combination of refund payments and a reduction in Attachment O of the MISO tariff and grandfathered agreement rates over the preceding 12 months.

Transmission ROE

Two complaints were filed with FERC seeking to reduce the ROE component of the transmission rates that MISO transmission owners, including Cleco, may collect under the MISO tariff. The complaints sought to reduce the 12.38% ROE used in MISO’s transmission rates to a proposed 6.68%. The

complaints covered the period December 2013 through May 2016. In June 2016, an administrative law judge issued an initial decision in the second rate case docket recommending a 9.70% base ROE. In September 2016, FERC issued a Final Order in response to the first complaint establishing a 10.32% ROE. However, on November 21, 2019, FERC voted to adopt a new methodology for evaluating base ROE for public utilities under the Federal Power Act. In addition, FERC set the MISO transmission owners’ region-wide base ROE at 9.88% for the refund period covered in the first complaint and going forward. The draft FERC order further found that complainants in the second complaint proceeding failed to show that the 9.88% base ROE was unjust and unreasonable and thus dismissed the second complaint. On May 21, 2020, FERC issued Opinion No. 569-A, which granted rehearing in part of Opinion No. 569, which had revised FERC’s methodology for analyzing the base ROE component of public utility rates under section 206 of the Federal Power Act. Opinion No. 569-A further refines FERC’s ROE methodology and finds that the MISO Transmission Owners’ base ROE should be set at 10.02% instead of 9.88%. Cleco Power is unable to determine when a final FERC Order will be issued. As of June 30, 2021, Cleco Power had $0.3 million accrued for the change in the ROE.

In November 2014, the MISO transmission owners committee, of which Cleco is a member, filed a request with FERC for an incentive to increase the new ROE by 50 basis points for RTO participation as allowed by the MISO tariff. In January 2015, FERC granted the request. The collection of the adder was included in MISO’s transmission rates for a total ROE of 10.38% and 10.52% beginning January 1, 2020, and June 1, 2020, respectively.

South Central Generating

In 2017, Louisiana Generating received insurance settlement proceeds for costs incurred to resolve a lawsuit which was brought by the EPA and the Louisiana Department of Environmental Quality against Louisiana Generating related to Big Cajun II, Unit 3. Entergy Gulf States, as co-owner of Big Cajun II, Unit 3, is expected to be allocated a portion of the insurance settlement proceeds. Any amount allocated to Entergy Gulf States will be determined by ongoing litigation and negotiations. South Central Generating estimated this amount to be $10.0 million. As part of the Cleco Cajun Transaction, Cleco Cajun assumed the $10.0 million contingent liability and NRG Energy indemnified Cleco for losses associated with this litigation matter. As a result, Cleco also recorded a $10.0 million indemnification asset in Other current assets on Cleco’s Condensed Consolidated Balance Sheets as part of the Cleco Cajun Transaction.

Prior to the Cleco Cajun Transaction, South Central Generating was involved in various litigation matters, including environmental and contract proceedings, before various courts regarding matters arising out of the ordinary course of business. As of June 30, 2021, management estimates potential losses to be $1.5 million with respect to one of these matters. Management is unable to estimate any potential losses Cleco Cajun may be ultimately responsible for with respect to any of the remaining matters. As part of the Cleco Cajun Transaction, NRG Energy indemnified Cleco for losses as of the closing date associated with matters that existed as of the closing date, including pending litigation.

Other

Cleco is involved in various litigation matters, including regulatory, environmental, and administrative proceedings before various courts, regulatory commissions, arbitrators, and governmental agencies regarding matters arising in the ordinary course of business. The liability Cleco may ultimately incur with respect to any one of these matters may be in excess of amounts currently accrued. Management regularly analyzes current information and, as of June 30, 2021, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters are $3.8 million and has accrued this amount.

Off-Balance Sheet Commitments and Guarantees

Cleco Holdings and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Holdings’ subsidiaries and equity investees (affiliates). Cleco Holdings and Cleco Power have also agreed to contractual terms that require the Registrants to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees.

Cleco Holdings entered into these off-balance sheet commitments in order to entice desired counterparties to contract with its affiliates by providing some measure of credit assurance to the counterparty in the event Cleco’s affiliates do not fulfill certain contractual obligations. If Cleco Holdings had not provided the off-balance sheet commitments, the desired counterparties may not have contracted with Cleco’s affiliates, or may have contracted with them at terms less favorable to its affiliates.

The off-balance sheet commitments are not recognized on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets because management has determined that Cleco and Cleco Power’s affiliates are able to perform the obligations under their contracts and that it is not probable that payments by Cleco or Cleco Power will be required.

Cleco Holdings provided guarantees and indemnities to Entergy Louisiana and Entergy Gulf States as a result of the sale of the Perryville generation facility in 2005. The remaining indemnifications relate to environmental matters that may have been present prior to closing. These remaining indemnifications have no time limitations. The maximum amount of the potential payment to Entergy Louisiana and Entergy Gulf States is $42.4 million. Management does not expect to be required to pay Entergy Louisiana and Entergy Gulf States under these guarantees.

On behalf of Acadia, Cleco Holdings provided guarantees and indemnifications as a result of the sales of Acadia Unit 1 to Cleco Power and Acadia Unit 2 to Entergy Louisiana in 2010 and 2011, respectively. The remaining indemnifications relate to the fundamental organizational structure of Acadia. These remaining indemnifications have no time limitations or maximum potential future payments. Management does not expect to be required to pay Cleco Power or Entergy Louisiana under these guarantees.

Cleco Holdings provided indemnifications to Cleco Power as a result of the transfer of Coughlin to Cleco Power in March 2014. Cleco Power also provided indemnifications to Cleco Holdings and Evangeline as a result of the transfer of Coughlin to Cleco Power. The maximum amount of the potential payment to Cleco Power, Cleco Holdings, and Evangeline for their respective indemnifications is $40.0 million, except for indemnifications relating to the fundamental organizational

structure of each respective entity, of which the maximum amount is $400.0 million. Management does not expect to be required to make any payments under these indemnifications.

As part of the Amended Lignite Mining Agreement, Cleco Power and SWEPCO, joint owners of the Dolet Hills Power Station, have agreed to pay the loan and lease principal obligations of the lignite miner, DHLC, when due if DHLC does not have sufficient funds or credit to pay. Any amounts paid on behalf of the miner would be credited by the lignite miner against future invoices for lignite delivered. As of June 30, 2021, the maximum projected payment by Cleco Power under this guarantee is estimated to be $25.0 million; however, the Amended Lignite Mining Agreement does not contain a cap. The projection is based on the forecasted loan and lease obligations to be incurred by DHLC, primarily for purchases of equipment. Cleco Power has the right to dispute the incurrence of loan and lease obligations through the review of the mining plan before the incurrence of such loan and lease obligations. In April 2020, Cleco Power and SWEPCO mutually agreed to not develop additional mining areas for future lignite extraction and subsequently provided notice to the LPSC of the intent to cease mining at the Dolet Hills and Oxbow mines by June 2020. The mine closures are subject to LPSC review and approval. As of December 31, 2020, all lignite reserves intended to be extracted from the Oxbow mine had been extracted. On October 6, 2020, Cleco Power and SWEPCO made a joint filing with the LPSC seeking authorization to close the Oxbow mine and to include and defer certain accelerated mine closing costs in fuel and related ratemaking treatment. On March 19, 2021, the LPSC approved the establishment of a regulatory asset for the deferral of certain accelerated mine costs in fuel and related ratemaking treatment. Cleco Power is currently responding to data requests related to the joint filing. The Amended Lignite Mining Agreement does not affect the amount the Registrants can borrow under their credit facilities. Currently, management does not expect to be required to pay DHLC under this guarantee.

Cleco Holdings, in relation to Cleco Cajun’s participation in MISO, and Cleco Power have letters of credit to MISO pursuant to energy market requirements. The letters of credit automatically renew each year and have no impact on Cleco Holdings’ or Cleco Power’s revolving credit facility. In February 2021, as a result of Winter Storms Uri and Viola, Cleco Power and Cleco Holdings, on behalf of Cleco Cajun, were required to post collateral with MISO. In March 2021, Cleco Power and Cleco Cajun settled with MISO the purchased power obligations associated with Winter Storms Uri and Viola. MISO returned associated collateral postings of $24.9 million and $6.5 million to Cleco Power and Cleco Holdings, respectively. For more information on these winter storms, see Note 17 — “Storm Restoration — Winter Storms Uri and Viola.”

Generally, neither Cleco Holdings nor Cleco Power has recourse that would enable them to recover amounts paid under their guarantee or indemnification obligations. There are no assets held as collateral for third parties that either Cleco Holdings or Cleco Power could obtain and liquidate to recover amounts paid pursuant to the guarantees or indemnification obligations.

Other Commitments

Cleco has accrued for liabilities related to third parties, employee medical benefits, and AROs.

Risks and Uncertainties

Cleco could be subject to possible adverse consequences if Cleco’s counterparties fail to perform their obligations or if Cleco or its affiliates are not in compliance with loan agreements or bond indentures.

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows.

Changes in the regulatory environment or market forces could cause Cleco to determine its assets have suffered an other-than-temporary decline in value, whereby an impairment would be required, and Cleco’s financial condition could be materially adversely affected.

Cleco Power and Cleco Cajun are participants in the MISO market. Energy prices in the MISO market are based on LMP, which includes a component directly related to congestion on the transmission system. Pricing zones with greater transmission congestion may have higher LMPs. Physical transmission constraints present in the MISO market could increase energy costs within pricing zones. Cleco Power and Cleco Cajun use FTRs to mitigate transmission congestion price risks. Changes to anticipated transmission paths may result in an unexpected increase in energy costs.

On March 1, 2019, Cleco Power began to operate the Dolet Hills Power Station from June through September of each year; however, the Dolet Hills Power Station will continue to be available to operate in other months, if needed. In June 2020, after thorough evaluation, management decided to retire the Dolet Hills Power Station.

Cleco Power anticipates filing an application in the third quarter of 2021 with the LPSC giving notice that the Dolet Hills Power Station will be retired at the end of 2021.

In June 2020, Cleco Power remeasured its ARO liabilities due to the expected retirement of the Dolet Hills Power Station. Cleco Power’s ARO liability increased $3.3 million as a result of this remeasurement. At June 30, 2021, Cleco Power’s undivided interest in the Dolet Hills Power Station was $62.6 million and was included in base rates.

In April 2020, Cleco Power and SWEPCO mutually agreed to not develop additional mining areas for future lignite extraction and subsequently provided notice to the LPSC of the intent to cease mining at the Dolet Hills and Oxbow mines by June 2020, subject to LPSC review and approval. As of December 31, 2020, all lignite reserves intended to be extracted from the Oxbow mine had been extracted. On October 6, 2020, Cleco Power and SWEPCO made a joint filing with the LPSC seeking authorization to close the Oxbow mine, and to include and defer certain accelerated mine closing costs in fuel and related ratemaking treatment. The expected early closure of the mines has resulted in increased costs that will be billed through the fuel adjustment clause, which management currently believes are recoverable. Management does not believe the early closure of the mines will have an adverse impact on the recovery value of the Dolet Hills Power Station. On March 19, 2021, the LPSC approved the establishment of a regulatory asset for the deferral of certain accelerated mine costs in fuel and related ratemaking treatment. Cleco Power expects to have sufficient lignite fuel available to continue seasonal operations of the Dolet Hills Power Station through the end of 2021. Cleco Power is currently responding to data requests related to the joint filing.

Fuel costs incurred by the Dolet Hills Power Station are recoverable by Cleco Power through active fuel adjustment clauses. Under the Amended Lignite Mining Agreement, DHLC

bills Cleco Power its proportionate share of incurred lignite extraction and associated mining-related costs as fuel is delivered. As of June 30, 2021, DHLC estimates $96.1 million of costs will be billed to Cleco Power prior to the closure of the Dolet Hills Power Station. In 2009, Cleco Power acquired an interest in Oxbow, which owns mineral rights and land leases. Under a joint operating agreement pertaining to the Oxbow mineral rights and land leases, Oxbow bills Cleco Power its proportionate share of incurred costs. As of June 30, 2021, Oxbow estimates approximately $6.6 million of costs will be billed to Cleco Power prior to the closure of the Dolet Hills Power Station. If any of these costs are not recoverable, it could materially impact the Registrants’ results of operations, financial condition, or cash flows.

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Affiliate Transactions

6 Months Ended

Jun. 30, 2021

Related Party Transactions [Abstract]

Affiliate Transactions

Note 14 — Affiliate Transactions

At June 30, 2021, and December 31, 2020, Cleco Holdings had an affiliate receivable of $2.7 million and $1.7 million, respectively, from Cleco Group primarily for franchise taxes. At both June 30, 2021, and December 31, 2020, Cleco Holdings had an affiliate payable of $41.3 million to Cleco Group primarily for settlement of taxes payable. At both June 30, 2021, and December 31, 2020, Cleco Power had an affiliate payable to Cleco Holdings for $57.7 million, of which $57.6 million was for settlement of taxes payable.

Cleco Power has balances that are payable to or due from its affiliates. The following table is a summary of those balances:

	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	10,383	$	57,696	$	10,353	$	57,713
Support Group	1,707		12,737		3,248		14,355
Cleco Cajun	936		4		1,004		—
Total	$	13,026	$	70,437	$	14,605	$	72,068

Oxbow bills Cleco Power its proportionate share of incurred costs related to mineral rights and land leases. These costs are included in fuel inventory and are recoverable from Cleco Power customers through the LPSC-established FAC or related wholesale contract provisions. During the three and six months ended June 30, 2021, Cleco Power recorded $0.9 million and $1.9 million, respectively, of its proportionate share of incurred costs. During the three and six months ended June 30, 2020, Cleco Power recorded $14.6 million and $15.5 million, respectively, of its proportionate share of incurred costs. At both June 30, 2021, and December 31, 2020, Cleco Power had $0.3 million payable to Oxbow. For more information on Cleco Power’s variable interest in Oxbow, see Note 12 — “Variable Interest Entities.”

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Intangible Assets and Liabilities

6 Months Ended

Jun. 30, 2021

Intangible Assets And Liabilities Disclosure [Abstract]

Intangible Assets and Liabilities

Note 15 — Intangible Assets and Liabilities

During 2008, Cleco Katrina/Rita acquired a $177.5 million intangible asset which includes $176.0 million for the right to bill and collect storm recovery charges from customers of Cleco Power and $1.5 million of financing costs. This intangible asset was fully amortized in March 2020 and had no residual value at the end of its life.

As a result of the 2016 Merger, fair value adjustments were recorded on Cleco’s Condensed Consolidated Balance Sheet for the valuation of the Cleco trade name and long-term

wholesale power supply agreements. At the end of their lives, these intangible assets will have no residual value. The trade name intangible asset is being amortized over its estimated economic useful life of 20 years. The intangible assets related to the power supply agreements are amortized over the estimated life of each applicable contract ranging between 7 and 19 years, and the amortization is included in Electric operations on Cleco’s Condensed Consolidated Statements of Income.

As a result of the Cleco Cajun Transaction, fair value adjustments were recorded on Cleco’s Condensed Consolidated Balance Sheet for the difference between the contract and market price of acquired long-term wholesale power agreements. At the end of their lives, these intangible assets and liabilities will have no residual value. These intangibles are amortized over the estimated life of each applicable contract ranging between 2 and 8 years. The amortization is included in Electric operations on Cleco’s Condensed Consolidated Statements of Income.

As part of the Cleco Cajun Transaction, Cleco assumed an LTSA for maintenance services related to the Cottonwood Plant. This intangible liability is being amortized using the straight-line method over the estimated life of the LTSA of seven years. The amortization is included as a reduction to the LTSA prepayments on Cleco’s Condensed Consolidated Balance Sheet.

The following tables present Cleco and Cleco Power’s amortization of intangible assets and liabilities:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Intangible assets
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	—	$	—	$	—	$	517
Trade name	$	64	$	64	$	128	$	128
Power supply agreements	$	6,400	$	6,400	$	12,800	$	12,800
Intangible liabilities
LTSA	$	871	$	871	$	1,742	$	1,742
Power supply agreements	$	718	$	882	$	1,600	$	1,764

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	—	$	—	$	—	$	517

The following tables summarize the balances for intangible assets and liabilities subject to amortization for Cleco:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Intangible assets
Trade name	$	5,100	$	5,100
Power supply agreements	184,004		184,004
Total intangible assets carrying amount	189,104		189,104
Intangible liabilities
LTSA	24,100		24,100
Power supply agreements	14,200		14,200
Total intangible liability carrying amount	38,300		38,300
Net intangible assets carrying amount	150,804		150,804
Accumulated amortization	(73,517)		(63,932)
Net intangible assets subject to amortization	$	77,287	$	86,872

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Accumulated Other Comprehensive Loss

6 Months Ended

Jun. 30, 2021

Equity [Abstract]

Accumulated Other Comprehensive Loss

Note 16 — Accumulated Other Comprehensive Loss

The components of accumulated other comprehensive loss are summarized in the following tables for Cleco and Cleco Power. All amounts are reported net of income taxes. Amounts in parentheses indicate debits.

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30, 2021		FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(25,168)	$	(25,796)
Amounts reclassified from AOCI
Amortization of postretirement benefit net (gain) loss	(420)		208
Balances, June 30, 2021	$	(25,588)	$	(25,588)

	FOR THE THREE MONTHS ENDED JUNE 30, 2020		FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(17,099)	$	(17,513)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	442		856
Balances, June 30, 2020	$	(16,657)	$	(16,657)

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2021						FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI		POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(18,681)	$	(5,550)	$	(24,231)	$	(19,139)	$	(5,614)	$	(24,753)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	287		—		287		745		—		745
Reclassification of net loss to interest charges	—		64		64		—		128		128
Balances, June 30, 2021	$	(18,394)	$	(5,486)	$	(23,880)	$	(18,394)	$	(5,486)	$	(23,880)

	FOR THE THREE MONTHS ENDED JUNE 30, 2020						FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI		POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(16,291)	$	(5,804)	$	(22,095)	$	(16,717)	$	(5,868)	$	(22,585)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	419		—		419		845		—		845
Reclassification of net loss to interest charges	—		64		64		—		128		128
Balances, June 30, 2020	$	(15,872)	$	(5,740)	$	(21,612)	$	(15,872)	$	(5,740)	$	(21,612)

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Storm Restoration

6 Months Ended

Jun. 30, 2021

Unusual or Infrequent Items, or Both [Abstract]

Storm Restorations

Note 17 — Storm Restoration

Hurricanes Laura, Delta, and Zeta

In August and October 2020, Cleco Power’s distribution and transmission systems sustained substantial damage from three separate hurricanes.

Cleco Power’s total storm restoration costs related to the hurricanes is approximately $243.0 million. The damage to equipment from the hurricanes required replacement, as well as repair of existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 63%, or approximately $152.4 million, of the total restoration costs recorded at June 30, 2021. At June 30, 2021, Cleco Power had regulatory assets for non-capital expenses related to Hurricanes Laura, Delta, and Zeta, as allowed by the LPSC, totaling $77.7 million.

On December 4, 2020, Cleco Power filed an application with the LPSC requesting an interim rate recovery for return on certain storm restoration costs associated with the hurricanes until securitization of such costs can be completed. On May 19, 2021, the LPSC issued an order authorizing Cleco Power to recover $16.0 million annually for interim storm recovery costs. This order is effective until such time that the LPSC issues its order authorizing the recovery of the verified final storm costs and securitization of those costs. Cleco Power began collecting this amount through rates on June 1, 2021.

On August 5, 2021, Cleco Power filed testimony with the LPSC relating to securitization of the final storm costs for Hurricanes Laura, Delta, and Zeta.

Cleco Power, in line with other impacted utilities, will seek available funds from the U.S. government for relief of costs incurred from Hurricanes Laura, Delta, and Zeta. Cleco Power cannot predict the likelihood that any reimbursement from the U.S. government ultimately will be approved.

Winter Storms Uri and Viola

In February 2021, Winter Storms Uri and Viola reached Louisiana causing Cleco’s service territories to experience extreme and unprecedented winter weather that resulted in

damage to Cleco Power’s distribution assets, electricity generation supply shortages, natural gas supply shortages, and increases in wholesale prices of natural gas in the United States, primarily due to prolonged freezing temperatures. Cleco Power’s current estimate of the total storm restoration costs related to Winter Storms Uri and Viola is approximately $10.5 million. The damage to equipment from the storms required replacement, as well as repair of the existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 80%, or approximately $8.4 million, of the estimated total restoration costs recorded at June 30, 2021. At June 30, 2021, Cleco Power had a regulatory asset for the remaining operations and maintenance costs of $2.0 million, as allowed by the LPSC. Cleco Power has requested recovery of these costs through the storm securitization filing that was made with the LPSC on August 5, 2021.

Cleco Power’s incremental fuel and purchased power costs incurred as a result of Winter Storms Uri and Viola is approximately $55.0 million. On March 29, 2021, Cleco Power received approval from the LPSC to recover $50.0 million of these costs over a period of 12 months beginning in May 2021. On May 11, 2021, Cleco Power received notice of an audit from the LPSC for the fuel costs incurred during the time period required to restore services to Cleco Power’s customers during Winter Storms Uri and Viola. Management is unable to determine the outcome or timing of the audit.

Cleco Cajun's incremental negative impact of Winter Storms Uri and Viola on operations is approximately $11.2 million. The incremental impact to Cleco Cajun’s operations is subject to final settlement.

In February 2021, as a result of Winter Storms Uri and Viola, Cleco Power and Cleco Holdings, on behalf of Cleco Cajun, were required to post collateral with MISO. In March 2021, Cleco Power and Cleco Cajun settled with MISO the purchased power obligations associated with Winter Storms Uri and Viola. MISO returned associated collateral postings of $24.9 million and $6.5 million to Cleco Power and Cleco Holdings, respectively.

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Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 2021

Accounting Policies [Abstract]

Covid-19 Impacts

In March 2020, WHO declared the outbreak of COVID-19 to be a global pandemic, and the U.S. declared a national emergency. In response to these declarations and the rapid spread of COVID-19, federal, state and local governments imposed varying degrees of restrictions on business and social activities to contain COVID-19, including quarantine and “stay-at-home” orders and directives in Cleco’s service territory. State and local authorities also subsequently implemented multistep policies to reopen various sectors of the economy such as retail establishments, health and personal care businesses, and restaurants, among others. During March and April 2021, due to the reduction in new COVID-19 cases and hospitalizations and the availability of COVID-19 vaccines, the governor of the state of Louisiana reduced restrictions that were previously in effect, eased capacity limits on businesses and social gatherings, and revoked the mandatory, state-wide mask mandate. However, effective August 4, 2021, the state-wide mask mandate was reinstated due to a surge in COVID-19 cases.

The COVID-19 pandemic may worsen in the U.S. during the upcoming months, which may cause federal, state, and local governments to reconsider restrictions on business and social activities. In the event governments reinstate or increase restrictions, the reopening of the economy may be further curtailed.

Cleco has modified some of its business operations, as these restrictions have significantly impacted many sectors of the economy. Impacts include record levels of unemployment, with businesses, nonprofit organizations, and governmental entities modifying, curtailing, or ceasing normal operations. Cleco is monitoring the ongoing COVID-19 pandemic and continues to adjust certain business practices to conform to government restrictions and best practices encouraged by the CDC, WHO, and other governmental and regulatory authorities.

Cleco cannot predict the full impact that COVID-19, or the significant disruption and volatility currently being experienced in the markets, will have on its business, cash flows, liquidity, financial condition, and results of operations at this time, due to numerous uncertainties. The ultimate impacts will depend on future developments, including, among others, the ultimate geographic spread of COVID-19, the consequences of governmental and other measures designed to prevent the spread of COVID-19, the availability, timely distribution and acceptance of effective treatments and vaccines, the duration of the pandemic, actions taken by governmental authorities, customers, suppliers and other third parties, workforce availability, and the timing and extent to which normal economic and operating conditions resume.

Principles of Consolidation

The accompanying condensed consolidated financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Basis of Presentation

The condensed consolidated financial statements of Cleco and Cleco Power have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these condensed consolidated financial statements do not include all of the information and notes required by GAAP for annual financial statements. The year-end condensed consolidated balance sheet data was derived from audited financial statements. Because the interim condensed consolidated financial statements and the accompanying notes do not include all of the information and notes required by GAAP for annual financial statements, the condensed consolidated financial statements and other information included in this Quarterly Report on Form 10-Q should be read in conjunction with the consolidated financial statements and accompanying notes in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2020. These condensed consolidated financial statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly state the financial position and results of operations of Cleco and Cleco Power. Amounts reported in Cleco and Cleco Power’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, discrete income tax items, and other factors.In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates.

Restricted Cash and Cash Equivalents

Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general corporate purposes.Prior to the repayment of the storm recovery bonds in March 2020, Cleco Katrina/Rita had the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash was collected, it was restricted for payment of administrative fees, interest, and principal on the storm recovery bonds.

Reserves for Credit Losses

Customer accounts receivable are recorded at the invoiced amount and do not bear interest. Customer accounts receivable are generally considered to become past due 20 days after the billing date. Cleco recognizes write-offs within the allowance for credit losses once all recovery methods have been exhausted. It is the policy of management to review accounts receivable and unbilled revenue monthly using a reserve matrix based on historical bad debt write-offs, as well as current and forecasted economic conditions, to establish a credit loss estimate. Management’s historical credit loss analysis included periods of economic recessions, natural disasters, and temporary changes to collection policies. Due to the critical necessity of electricity, none of these past events have significantly impacted Cleco’s credit loss rates. Although Cleco’s service territory experienced a recent decline in the economy in 2020 and 2021 primarily related to the COVID-19 pandemic and weather-related events, the economic outlook at June 30, 2021, was still within range of its historical credit loss analysis.

Recent Authoritative Guidance

In March 2020, FASB issued optional guidance for a limited period of time that applies to entities meeting certain criteria for the contract modifications or hedging relationships that are referencing LIBOR or another reference rate expected to be discontinued due to reference rate reform. The guidance includes a general principal that permits an entity to consider contract modifications due to reference rate reform to be an event that does not require contract remeasurement at the modification date or reassessment of a previous accounting determination. The optional guidance may be applied from March 12, 2020, through December 31, 2022. Management has identified contracts with reference rates that will be discontinued, primarily related to long-term debt obligations. In the second quarter of 2021, certain debt contracts were amended to include fallback provisions that provide substitute reference rates upon the discontinuance of LIBOR, among other amendments. Management will continue to modify

contracts to include similar fallback language and expects to apply this guidance on an ongoing basis. Management does not expect this guidance to have a significant impact on the Registrants’ results of operations, financial condition, or cash flows.

In December 2019, FASB amended the guidance for accounting for income taxes. The amendments simplify the accounting for income taxes by removing certain exceptions to general principles included in the accounting guidance. Effective January 1, 2021, Cleco adopted the amended accounting guidance. Adoption of this guidance did not materially impact the Registrants’ results of operations, financial condition, or cash flows.

Regulatory Assets and Liabilities

Cleco Power capitalizes or defers certain costs for recovery from customers and recognizes a liability for amounts expected to be returned to customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered or refunded through the ratemaking process.

Under the current regulatory environment, Cleco Power believes these regulatory assets will be fully recoverable; however, if in the future, as a result of regulatory changes or

competition, Cleco Power’s ability to recover these regulatory assets would no longer be probable, then to the extent that such regulatory assets were determined not to be recoverable, Cleco Power would be required to write-down such assets. In addition, potential deregulation of the industry or possible future changes in the method of rate regulation of Cleco Power could require discontinuance of the application of the authoritative guidance on regulated operations.

Pension Plan and Employee Benefits

Employees hired before August 1, 2007, are covered by a non-contributory, defined benefit pension plan. Based on the funding assumptions at December 31, 2020, and the funding relief provided by the American Rescue Plan Act, which was signed by the President on March 11, 2021, management

estimates that no pension contributions will be required through 2025. As of June 30, 2021, Cleco expects to make $67.0 million in discretionary contributions to the pension plan in 2021, which would offset future required contributions.

Cleco Power is the plan sponsor and Support Group is the plan administrator. Benefits under the plan reflect an employee’s years of service, age at retirement, and accrued benefit at retirement.

Cleco’s retirees may be eligible to receive Other Benefits. Dependents of Cleco’s retirees may also be eligible to receive Other Benefits with the exception of life insurance benefits.

The non-service components of net periodic pension and Other Benefits cost are included in Other income (expense), net within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. Certain Cleco officers are covered by SERP. Cleco does not fund the SERP liability, but instead pays for current benefits out of general funds available. Cleco Power has formed a rabbi trust. The life insurance policies issued on SERP participants designate the rabbi trust as the beneficiary. Market conditions could have a significant impact on the cash surrender value of the life insurance policies. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ death benefits, as well as future SERP payments. However, because SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. All SERP benefits are paid out of general cash available of the respective companies that employed the officer. Cleco Power is the plan sponsor and Support Group is the plan administrator.The non-service components of net periodic benefit cost related to SERP are included in Other income (expense), net within Cleco and Cleco Power’s Condensed Consolidated Statements of Income.Cleco’s 401(k) Plan is intended to provide active, eligible employees with voluntary, long-term savings and investment opportunities. The 401(k) Plan is a defined contribution plan and is subject to the applicable provisions of the Employee Retirement Income Security Act of 1974. In accordance with the 401(k) Plan, employer contributions are made in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Participation in the Plan is voluntary, and active Cleco employees are eligible to participate.

Income Taxes

Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense.Cleco classifies income tax penalties as a component of other expense.

Variable Interest Entities

Cleco and Cleco Power apply the equity method of accounting to report the investment in Oxbow in the consolidated financial statements. Under the equity method, the assets and liabilities of this entity are reported as Equity investment in investee on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of this entity are netted and reported as equity income or loss from investees on Cleco and Cleco Power’s Condensed Consolidated Statements of Income.

Equity Method Investments

Cleco and Cleco Power apply the equity method of accounting to report the investment in Oxbow in the consolidated financial statements. Under the equity method, the assets and liabilities of this entity are reported as Equity investment in investee on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of this entity are netted and reported as equity income or loss from investees on Cleco and Cleco Power’s Condensed Consolidated Statements of Income.

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Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2021

Restricted Cash and Cash Equivalents Items [Line Items]

Restricted Cash and Cash Equivalents

Cleco and Cleco Power’s restricted cash and cash equivalents consisted of the following:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current
Cleco Katrina/Rita’s storm recovery bonds	$	1,673	$	2,626
Cleco Power’s charitable contributions	1,078		1,718
Cleco Power’s rate credit escrow	198		201
Total current	2,949		4,545
Non-current
Diversified Lands’ mitigation escrow	22		22
Cleco Cajun’s defense fund	722		722
Total non-current	744		744
Total restricted cash and cash equivalents	$	3,693	$	5,289

Changes in Allowance for Credit Losses, Other

The tables below present the changes in the allowance for credit losses by receivable for Cleco and Cleco Power:

Cleco
			FOR THE THREE MONTHS  ENDED JUNE 30, 2021						FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	ACCOUNTS RECEIVABLE		OTHER*		TOTAL		ACCOUNTS RECEIVABLE		OTHER*		TOTAL
Balances, beginning of period	$	2,040	$	1,638	$	3,678	$	2,758	$	1,638	$	4,396
Current period provision	616		—		616		2,490		—		2,490
Charge-offs	(1,583)		—		(1,583)		(4,442)		—		(4,442)
Recovery	261		—		261		528		—		528
Balances, June 30, 2021	$	1,334	$	1,638	$	2,972	$	1,334	$	1,638	$	2,972

* Loan held at Diversified Lands that was fully reserved for at June 30, 2021.

			FOR THE THREE MONTHS  ENDED JUNE 30, 2020						FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE		OTHER*		TOTAL		ACCOUNTS RECEIVABLE		OTHER*		TOTAL
Balances, beginning of period	$	2,123	$	1,638	$	3,761	$	3,005	$	1,250	$	4,255
CECL adoption	—		—		—		71		—		71
Current period provision	1,137		—		1,137		3,634		388		4,022
Charge-offs	—		—		—		(4,091)		—		(4,091)
Recovery	226		—		226		867		—		867
Balances, June 30, 2020	$	3,486	$	1,638	$	5,124	$	3,486	$	1,638	$	5,124

* Loan held at Diversified Lands that was fully reserved for at June 30, 2020.

Changes in Allowance for Credit Losses, Accounts Receivable

The tables below present the changes in the allowance for credit losses by receivable for Cleco and Cleco Power:

Cleco
			FOR THE THREE MONTHS  ENDED JUNE 30, 2021						FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	ACCOUNTS RECEIVABLE		OTHER*		TOTAL		ACCOUNTS RECEIVABLE		OTHER*		TOTAL
Balances, beginning of period	$	2,040	$	1,638	$	3,678	$	2,758	$	1,638	$	4,396
Current period provision	616		—		616		2,490		—		2,490
Charge-offs	(1,583)		—		(1,583)		(4,442)		—		(4,442)
Recovery	261		—		261		528		—		528
Balances, June 30, 2021	$	1,334	$	1,638	$	2,972	$	1,334	$	1,638	$	2,972

* Loan held at Diversified Lands that was fully reserved for at June 30, 2021.

			FOR THE THREE MONTHS  ENDED JUNE 30, 2020						FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE		OTHER*		TOTAL		ACCOUNTS RECEIVABLE		OTHER*		TOTAL
Balances, beginning of period	$	2,123	$	1,638	$	3,761	$	3,005	$	1,250	$	4,255
CECL adoption	—		—		—		71		—		71
Current period provision	1,137		—		1,137		3,634		388		4,022
Charge-offs	—		—		—		(4,091)		—		(4,091)
Recovery	226		—		226		867		—		867
Balances, June 30, 2020	$	3,486	$	1,638	$	5,124	$	3,486	$	1,638	$	5,124

* Loan held at Diversified Lands that was fully reserved for at June 30, 2020.

CLECO POWER

Restricted Cash and Cash Equivalents Items [Line Items]

Restricted Cash and Cash Equivalents

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current
Cleco Katrina/Rita’s storm recovery bonds	$	1,673	$	2,626
Charitable contributions	1,078		1,718
Rate credit escrow	198		201
Total restricted cash and cash equivalents	$	2,949	$	4,545

Changes in Allowance for Credit Losses, Accounts Receivable

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2021		FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	ACCOUNTS RECEIVABLE
Balances, beginning of period	$	2,040	$	2,758
Current period provision	616		2,490
Charge-offs	(1,583)		(4,442)
Recovery	261		528
Balances, June 30, 2021	$	1,334	$	1,334

	FOR THE THREE MONTHS ENDED JUNE 30, 2020		FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE
Balances, beginning of period	$	2,123	$	3,005
CECL adoption	—		71
Current period provision	1,137		3,634
Charge-offs	—		(4,091)
Recovery	226		867
Balances, June 30, 2020	$	3,486	$	3,486

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Leases (Tables)

6 Months Ended

Jun. 30, 2021

Leases [Abstract]

Lease Income Under Cottonwood Sale Leaseback

Cleco Cajun’s lease income under the Cottonwood Sale Leaseback is included in Other operations within Cleco’s Condensed Consolidated Statement of Income. Cleco Cajun’s lease income under the Cottonwood Sale Leaseback for the three and six months ended June 30, 2021, and 2020, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE. 30,
(THOUSANDS)	2021		2020		2021		2020
Fixed payments	$	10,000	$	10,000	$	20,000	$	20,000
Variable payments	5,010		5,194		10,475		10,760
Amortization of deferred lease liability*	2,301		2,301		4,603		4,603
Total lease income	$	17,311	$	17,495	$	35,078	$	35,363

* Consists of amortization of the deferred lease revenue resulting from the fair value of the lease between Cottonwood Energy and a special-purpose entity that is a subsidiary of NRG Energy.

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Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2021

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

Operating revenue, net for the three and six months ended June 30, 2021, and 2020, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	105,315		$	—		$	—		$	—	$	105,315
Commercial (1)	68,392			—			—			—		68,392
Industrial (1)	37,385			—			—			—		37,385
Other retail (1)	3,876			—			—			—		3,876
Electric customer credits	(19,054)			—			—			—		(19,054)
Total retail revenue	195,914			—			—			—		195,914
Wholesale, net	46,216		(1)	91,407			(2,420)		(2)			135,203
Transmission, net	13,313		(3)	13,573		(4)	—			(1,595)		25,291
Other	3,249			—			—			—		3,249
Affiliate (5)	1,224			—			26,120			(27,344)		—
Total revenue from contracts with customers	259,916			104,980			23,700			(28,939)		359,657
Revenue unrelated to contracts with customers
Other	1,763		(6)	17,326		(7)	1			2		19,092
Total revenue unrelated to contracts with customers	1,763			17,326			1			2		19,092
Operating revenue, net	$	261,679		$	122,306		$	23,701		$	(28,937)	$	378,749

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $(0.3) million of electric customer credits.

(4) Includes $(0.2) million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $15.0 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization.

	FOR THE THREE MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	97,973		$	—		$	—		$	—	$	97,973
Commercial (1)	61,575			—			—			—		61,575
Industrial (1)	29,208			—			—			—		29,208
Other retail (1)	3,341			—			—			—		3,341
Electric customer credits	(8,423)			—			—			—		(8,423)
Total retail revenue	183,674			—			—			—		183,674
Wholesale, net	45,694		(1)	84,733			(2,420)		(2)	—		128,007
Transmission, net	11,625		(3)	13,131			—			(1,639)		23,117
Other	3,601			—			—			—		3,601
Affiliate (4)	1,240			43			29,138			(30,421)		—
Total revenue from contracts with customers	245,834			97,907			26,718			(32,060)		338,399
Revenue unrelated to contracts with customers
Other	1,853		(5)	17,505		(6)	1			—		19,359
Total revenue unrelated to contracts with customers	1,853			17,505			1			—		19,359
Operating revenue, net	$	247,687		$	115,412		$	26,719		$	(32,060)	$	357,758

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $0.7 million of electric customer credits.

(4) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(5) Realized gains associated with FTRs.

(6) Includes $15.2 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization.

	FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	200,396		$	—		$	—		$	—	$	200,396
Commercial (1)	131,418			—			—			—		131,418
Industrial (1)	74,051			—			—			—		74,051
Other retail (1)	7,446			—			—			—		7,446
Electric customer credits	(40,030)			—			—			—		(40,030)
Total retail revenue	373,281			—			—			—		373,281
Wholesale, net	107,938		(1)	192,914			(4,840)		(2)	—		296,012
Transmission, net	27,295		(3)	28,830		(4)	—			(3,535)		52,590
Other	7,891			—			—			—		7,891
Affiliate (5)	2,879			—			53,276			(56,155)		—
Total revenue from contracts with customers	519,284			221,744			48,436			(59,690)		729,774
Revenue unrelated to contracts with customers
Other	8,859		(6)	35,108		(7)	2			—		43,969
Total revenue unrelated to contracts with customers	8,859			35,108			2			—		43,969
Operating revenue, net	$	528,143		$	256,852		$	48,438		$	(59,690)	$	773,743

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $(0.3) million of electric customer credits.

(4) Includes $(0.2) million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $30.5 million in lease revenue related to the Cottonwood Sale Leaseback and $4.6 million of deferred lease revenue amortization.

	FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	CLECO POWER			CLECO CAJUN			OTHER			ELIMINATIONS		TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	179,544		$	—		$	—		$	—	$	179,544
Commercial (1)	122,685			—			—			—		122,685
Industrial (1)	61,418			—			—			—		61,418
Other retail (1)	6,802			—			—			—		6,802
Surcharge	2,443			—			—			—		2,443
Electric customer credits	(16,763)			—			—			—		(16,763)
Total retail revenue	356,129			—			—			—		356,129
Wholesale, net	87,923		(1)	173,880			(4,840)		(2)	—		256,963
Transmission, net	23,694		(3)	26,062		(4)	—			(3,456)		46,300
Other	7,296			—			—			—		7,296
Affiliate (5)	2,346			204			58,415			(60,965)		—
Total revenue from contracts with customers	477,388			200,146			53,575			(64,421)		666,688
Revenue unrelated to contracts with customers
Other	3,259		(6)	35,382		(7)	1			—		38,642
Total revenue unrelated to contracts with customers	3,259			35,382			1			—		38,642
Operating revenue, net	$	480,647		$	235,528		$	53,576		$	(64,421)	$	705,330

(1) Includes fuel recovery revenue.

(2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements.

(3) Includes $0.7 million of electric customer credits.

(4) Includes $0.2 million of electric customer credits.

(5) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation.

(6) Realized gains associated with FTRs.

(7) Includes $30.8 million in lease revenue related to the Cottonwood Sale Leaseback and $4.6 million of deferred lease revenue amortization.

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Regulatory Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 2021

Regulatory Assets [Line Items]

Schedule of Regulatory Assets

The following table summarizes Cleco’s net regulatory assets and liabilities:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Total Cleco Power regulatory assets, net	$	429,976	$	275,469
2016 Merger adjustments *
Fair value of long-term debt	115,852		119,553
Postretirement costs	14,418		15,411
Financing costs	7,419		7,592
Debt issuance costs	5,086		5,254
Total Cleco regulatory assets, net	$	572,751	$	423,279

* Cleco regulatory assets include acquisition accounting adjustments as a result of the 2016 Merger.

CLECO POWER

Regulatory Assets [Line Items]

Schedule of Regulatory Assets

The following table summarizes Cleco Power’s regulatory assets and liabilities:

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Regulatory assets
Acadia Unit 1 acquisition costs	$	1,966	$	2,019
Accumulated deferred fuel	75,295		28,194
AFUDC equity gross-up *	68,122		69,670
Affordability study	13,644		—
AMI deferred revenue requirement	2,318		2,591
AROs	7,202		5,488
Coughlin transaction costs	861		876
COVID-19 executive order	2,953		2,953
Deferred storm restoration costs -   Hurricane Delta	17,802		17,051
Deferred storm restoration costs -   Hurricane Laura	56,412		54,406
Deferred storm restoration costs -   Hurricane Zeta	3,494		3,493
Deferred storm restoration costs -   Winter Storms Uri & Viola	1,980		—
Dolet Hills Power Station closure costs	91,479		48,982
Dolet Hills Mine closure costs	13,910		—
Emergency declarations	—		270
Energy efficiency	2,350		2,820
Financing costs	7,011		7,184
Interest costs	3,583		3,708
Madison Unit 3 property taxes	4,181		—
Non-service cost of postretirement benefits	10,881		9,901
Other	13,040		4,229
Postretirement costs	155,067		165,437
Production operations and maintenance expenses	2,664		4,058
Rodemacher Unit 2 deferred costs	4,115		1,333
St. Mary Clean Energy Center	6,959		3,479
Training costs	6,007		6,085
Tree trimming costs	10,450		11,807
Total regulatory assets	583,746		456,034
Regulatory liabilities
AFUDC	(5,359)		(4,218)
Corporate franchise tax, net	—		(763)
Deferred taxes, net	(148,411)		(175,584)
Total regulatory liabilities	(153,770)		(180,565)
Total regulatory assets, net	$	429,976	$	275,469
* Represents regulatory assets for past expenditures that were not earning a return on investment at June 30, 2021, and December 31, 2020, respectively. All other assets are earning a return on investment.

Schedule of Regulatory Liabilities

The following table summarizes Cleco Power’s regulatory assets and liabilities:

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Regulatory assets
Acadia Unit 1 acquisition costs	$	1,966	$	2,019
Accumulated deferred fuel	75,295		28,194
AFUDC equity gross-up *	68,122		69,670
Affordability study	13,644		—
AMI deferred revenue requirement	2,318		2,591
AROs	7,202		5,488
Coughlin transaction costs	861		876
COVID-19 executive order	2,953		2,953
Deferred storm restoration costs -   Hurricane Delta	17,802		17,051
Deferred storm restoration costs -   Hurricane Laura	56,412		54,406
Deferred storm restoration costs -   Hurricane Zeta	3,494		3,493
Deferred storm restoration costs -   Winter Storms Uri & Viola	1,980		—
Dolet Hills Power Station closure costs	91,479		48,982
Dolet Hills Mine closure costs	13,910		—
Emergency declarations	—		270
Energy efficiency	2,350		2,820
Financing costs	7,011		7,184
Interest costs	3,583		3,708
Madison Unit 3 property taxes	4,181		—
Non-service cost of postretirement benefits	10,881		9,901
Other	13,040		4,229
Postretirement costs	155,067		165,437
Production operations and maintenance expenses	2,664		4,058
Rodemacher Unit 2 deferred costs	4,115		1,333
St. Mary Clean Energy Center	6,959		3,479
Training costs	6,007		6,085
Tree trimming costs	10,450		11,807
Total regulatory assets	583,746		456,034
Regulatory liabilities
AFUDC	(5,359)		(4,218)
Corporate franchise tax, net	—		(763)
Deferred taxes, net	(148,411)		(175,584)
Total regulatory liabilities	(153,770)		(180,565)
Total regulatory assets, net	$	429,976	$	275,469
* Represents regulatory assets for past expenditures that were not earning a return on investment at June 30, 2021, and December 31, 2020, respectively. All other assets are earning a return on investment.

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Fair Value Accounting (Tables)

6 Months Ended

Jun. 30, 2021

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Carrying Value and Estimated Fair Value

The following tables summarize the carrying value and estimated market value of Cleco and Cleco Power’s financial instruments not measured at fair value on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets:

Cleco
	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	3,226,952	$	3,509,555	$	3,230,500	$	3,541,349

* The carrying value of long-term debt does not include deferred issuance costs of $12.8 million at
June 30, 2021, and $13.4 million at December 31, 2020.

Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis

The following tables disclose for Cleco and Cleco Power the fair value of financial assets and liabilities measured on a recurring basis:

Cleco
	FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS)	AT JUNE 30, 2021		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2020		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset description
Institutional money market funds	$	77,105	$	—	$	77,105	$	—	$	86,001	$	—	$	86,001	$	—
FTRs	8,662		—		—		8,662		4,805		—		—		4,805
Other commodity derivatives*	55,834		—		55,834		—		8,599		—		8,599		—
Total assets	$	141,601	$	—	$	132,939	$	8,662	$	99,405	$	—	$	94,600	$	4,805
Liability description
FTRs	$	1,161	$	—	$	—	$	1,161	$	1,625	$	—	$	—	$	1,625
Other commodity derivatives*	—		—		—		—		1,612		—		1,612		—
Total liabilities	$	1,161	$	—	$	—	$	1,161	$	3,237	$	—	$	1,612	$	1,625

* Other commodity derivatives include fixed price physical forwards and swap transactions.

Net Changes in Net Fair Value of FTR Assets and Liabilities Classified as Level 3

The following tables summarize the net changes in the net fair value of FTR assets and liabilities classified as Level 3 in the fair value hierarchy for Cleco and Cleco Power:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Beginning balance	$	1,023	$	1,096	$	3,180	$	5,778
Unrealized (losses) gains*	(1,005)		(284)		15,155		(371)
Purchases	9,958		9,267		10,806		9,732
Settlements	(2,475)		(2,039)		(21,640)		(7,099)
Ending balance	$	7,501	$	8,040	$	7,501	$	8,040
* Cleco Power’s unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet. Cleco Cajun’s unrealized (losses) gains are reported through Purchased power on Cleco’s Condensed Consolidated Income Statement.

Significant Unobservable Inputs Used in Developing Fair Value of Level 3 Positions

The following tables quantify the significant unobservable inputs used in developing the fair value of Level 3 positions for Cleco and Cleco Power as of June 30, 2021, and December 31, 2020:

Cleco
	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW		HIGH
FTRs at June 30, 2021	$	8,662	$	1,161	RTO auction pricing	FTR price - per MWh	$	(5.73)	$	7.28
FTRs at Dec. 31, 2020	$	4,805	$	1,625	RTO auction pricing	FTR price - per MWh	$	(3.49)	$	4.36

Institutional Money Market Funds

The following tables present the institutional money market funds in cash and cash equivalents and restricted cash and cash equivalents as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021, and December 31, 2020:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Cash and cash equivalents	$	73,412	$	80,712
Current restricted cash and cash equivalents	$	2,949	$	4,545
Non-current restricted cash and cash equivalents	$	744	$	744

Fair Value of Derivative Instruments as Recorded in Condensed Consolidated Balance Sheets

The following tables present the fair values of derivative instruments and their respective line items as recorded on

Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 2021, and December 31, 2020:

Cleco
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2021		AT DEC. 31, 2020
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	8,662	$	4,805
Current	Energy risk management liabilities	(1,161)		(1,625)
Other commodity derivatives
Current	Energy risk management assets	30,063		8,276
Non-current	Other deferred charges	25,771		323
Current	Energy risk management liabilities	—		(828)
Non-current	Other deferred credits	—		(784)
Commodity-related contracts, net		$	63,335	$	10,167

Amount of Gain (Loss) Recognized in Income on Derivatives

The following tables present the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2021, and 2020:

Cleco
	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	INCOME STATEMENT LINE ITEM	2021		2020		2021		2020
Commodity-related contracts
FTRs(1)	Electric operations	$	1,763	$	1,852	$	9,207	$	3,248
FTRs(1)	Purchased power	702		92		(7,858)		(289)
Other commodity derivatives	Fuel used for electric generation	(51,683)		9,316		(57,897)		2,208
Total		$	(49,218)	$	11,260	$	(56,548)	$	5,167

(1) For the three and six months ended June 30, 2021, unrealized losses associated with FTRs for Cleco Power of $0.4 million were reported through Accumulated deferred fuel on the balance sheet. For the three and six months ended June 30, 2020, unrealized losses associated with FTRs for Cleco Power of $1.3 million were reported through Accumulated deferred fuel on the balance sheet.

CLECO POWER

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Carrying Value and Estimated Fair Value

Cleco Power
	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,495,101	$	1,772,243	$	1,494,947	$	1,794,799

* The carrying value of long-term debt does not include deferred issuance costs of $6.9 million at
June 30, 2021, and $7.0 million at December 31, 2020.

Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis

Cleco Power
	FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS)	AT JUNE 30, 2021		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2020		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset description
Institutional money market funds	$	19,061	$	—	$	19,061	$	—	$	25,357	$	—	$	25,357	$	—
FTRs	6,867		—		—		6,867		4,337		—		—		4,337
Total assets	$	25,928	$	—	$	19,061	$	6,867	$	29,694	$	—	$	25,357	$	4,337
Liability description
FTRs	$	877	$	—	$	—	$	877	$	1,121	$	—	$	—	$	1,121
Total liabilities	$	877	$	—	$	—	$	877	$	1,121	$	—	$	—	$	1,121

Net Changes in Net Fair Value of FTR Assets and Liabilities Classified as Level 3

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Beginning balance	$	1,088	$	1,149	$	3,216	$	5,725
Unrealized (losses)gains*	(402)		1,298		(402)		1,298
Purchases	7,768		7,311		8,616		7,776
Settlements	(2,464)		(2,247)		(5,440)		(7,288)
Ending balance	$	5,990	$	7,511	$	5,990	$	7,511
* Unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheet.

Significant Unobservable Inputs Used in Developing Fair Value of Level 3 Positions

Cleco Power
	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW		HIGH
FTRs at June 30, 2021	$	6,867	$	877	RTO auction pricing	FTR price - per MWh	$	(2.03)	$	7.28
FTRs at Dec. 31, 2020	$	4,337	$	1,121	RTO auction pricing	FTR price - per MWh	$	(3.34)	$	4.36

Institutional Money Market Funds

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Cash and cash equivalents	$	16,112	$	20,812
Current restricted cash and cash equivalents	$	2,949	$	4,545

Fair Value of Derivative Instruments as Recorded in Condensed Consolidated Balance Sheets

Cleco Power
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2021		AT DEC. 31, 2020
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	6,867	$	4,337
Current	Energy risk management liabilities	(877)		(1,121)
Commodity-related contracts, net		$	5,990	$	3,216

Amount of Gain (Loss) Recognized in Income on Derivatives

Cleco Power
	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	INCOME STATEMENT LINE ITEM	2021		2020		2021		2020
Commodity-related contracts
FTRs(1)	Electric operations	$	1,763	$	1,852	$	9,208	$	3,249
FTRs(1)	Purchased power	(1,233)		(1,319)		(8,414)		(2,070)
Total		$	530	$	533	$	794	$	1,179

(1) For the three and six months ended June 30, 2021, unrealized losses associated with FTRs of $0.4 million were reported through Accumulated deferred fuel on the balance sheet. For the three and six months ended June 30, 2020, unrealized losses associated with FTRs of $1.3 million were reported through Accumulated deferred fuel on the balance sheet.

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Pension Plan and Employee Benefits (Tables)

6 Months Ended

Jun. 30, 2021

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net Periodic Pension and Other Benefits Cost

The components of net periodic pension and Other Benefits cost for the three and six months ended June 30, 2021, and 2020 were as follows:

	PENSION BENEFITS				OTHER BENEFITS
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	2,730	$	2,582	$	595	$	508
Interest cost	4,719		5,278		323		410
Expected return on plan assets	(5,698)		(6,242)		—		—
Amortizations
Prior period service credit	—		(15)		—		—
Net loss	5,607		4,477		384		340
Net periodic benefit cost	$	7,358	$	6,080	$	1,302	$	1,258

	PENSION BENEFITS				OTHER BENEFITS
	FOR THE SIX MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	5,258	$	4,910	$	1,190	$	1,015
Interest cost	9,334		10,408		645		820
Expected return on plan assets	(11,400)		(12,487)		—		—
Amortizations
Prior period service credit	—		(30)		—		—
Net loss	10,369		8,149		770		680
Net periodic benefit cost	$	13,561	$	10,950	$	2,605	$	2,515

The components of the net periodic benefit cost related to SERP for the three and six months ended June 30, 2021, and 2020 were as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Components of periodic benefit costs
Service cost	$	61	$	105	$	116	$	200
Interest cost	644		734		1,269		1,466
Amortizations
Prior period service credit	(55)		(67)		(107)		(107)
Net (gain) loss	(401)		835		613		1,592
Net periodic benefit cost	$	249	$	1,607	$	1,891	$	3,151

Current and Non-Current Portions of Other Benefits Liability

The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at June 30, 2021, and December 31, 2020, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	4,463	$	4,463
Non-current	$	51,522	$	51,868

The current and non-current portions of the SERP liability for Cleco and Cleco Power at June 30, 2021, and December 31, 2020, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	4,703	$	4,703
Non-current	$	91,355	$	92,522

Expense of the 401(k) Plan

Cleco’s 401(k) Plan expense for the three and six months ended June 30, 2021, and 2020 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
401(k) Plan expense	$	2,120	$	1,898	$	4,880	$	5,154

The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2021, and 2020 was as follows:

	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
401(k) Plan expense	$	946	$	832	$	2,326	$	2,495

CLECO POWER

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Current and Non-Current Portions of Other Benefits Liability

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	3,865	$	3,865
Non-current	$	40,449	$	40,734

Cleco Power
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Current	$	711	$	711
Non-current	$	19,364	$	19,828

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 2021

Effective Income Tax Rate [Line Items]

Effective Income Tax Rates

The following tables summarize the effective income tax rates for Cleco and Cleco Power for the three and six months ended June 30, 2021, and 2020:

Cleco
	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30
	2021		2020		2021		2020
Effective tax rate	11.1	%	23.9	%	0.4	%	23.4	%

CLECO POWER

Effective Income Tax Rate [Line Items]

Effective Income Tax Rates

Cleco Power
	FOR THE THREE MONTHS  ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2021		2020		2021		2020
Effective tax rate	24.6	%	24.9	%	(1.7)	%	24.1	%

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Disclosures about Segments (Tables)

6 Months Ended

Jun. 30, 2021

Segment Reporting [Abstract]

Segment Information

Segment Information for the Three Months Ended June 30,
2021 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	262,948	$	91,407		$	354,355
Other operations	16,269		30,655			46,924
Affiliate revenue	1,224		—			1,224
Electric customer credits	(18,762)		244			(18,518)
Operating revenue, net	$	261,679	$	122,306		$	383,985
Net income	$	27,421	$	52,494		$	79,915
Add: Depreciation and amortization	40,933		12,339		(1)	53,272
Less: Interest income	825		3			828
Add: Interest charges	18,237		(180)			18,057
Add: Federal and state income tax expense	8,956		18,063			27,019
EBITDA	$	94,722	$	82,713		$	177,435
(1) Includes $3.3 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(2.3) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2021 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	354,355	$	(2,420)		$	1	$	351,936
Other operations	46,924		1			(1,595)		45,330
Affiliate revenue	1,224		26,120			(27,344)		—
Electric customer credits	(18,518)		—			1		(18,517)
Operating revenue, net	$	383,985	$	23,701		$	(28,937)	$	378,749
Depreciation and amortization	$	53,272	$	4,427	(1)	$	—	$	57,699
Interest income	$	828	$	14		$	(13)	$	829
Interest charges	$	18,057	$	15,248		$	(14)	$	33,291
Federal and state income tax (benefit)	$	27,019	$	(17,182)		$	—	$	9,837
Net income (loss)	$	79,915	$	(1,093)		$	—	$	78,822
(1) Includes $2.4 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

2020 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	239,643	$	84,733		$	324,376
Other operations	15,904		30,636			46,540
Affiliate revenue	1,240		43			1,283
Electric customer credits	(9,100)		—			(9,100)
Operating revenue, net	$	247,687	$	115,412		$	363,099
Net income	$	28,233	$	26,762		$	54,995
Add: Depreciation and amortization	41,596		11,143		(1)	52,739
Less: Interest income	755		103			858
Add: Interest charges	18,603		120			18,723
Add: Federal and state income tax expense	9,356		8,601			17,957
EBITDA	$	97,033	$	46,523		$	143,556
(1) Includes $3.1 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(2.3) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2020 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	324,376	$	(2,420)		$	—	$	321,956
Other operations	46,540		1			(1,639)		44,902
Affiliate revenue	1,283		29,138			(30,421)		—
Electric customer credits	(9,100)		—			—		(9,100)
Operating revenue, net	$	363,099	$	26,719		$	(32,060)	$	357,758
Depreciation and amortization	$	52,739	$	4,565	(1)	$	—	$	57,304
Interest income	$	858	$	55		$	(15)	$	898
Interest charges	$	18,723	$	16,007		$	(15)	$	34,715
Federal and state income tax expense (benefit)	$	17,957	$	(4,364)		$	—	$	13,593
Net income (loss)	$	54,995	$	(11,826)		$	(1)	$	43,168
(1) Includes $2.4 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

Segment Information for the Six Months Ended June 30,
2021 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	530,107	$	192,914		$	723,021
Other operations	34,895		63,694			98,589
Affiliate revenue	2,879		—			2,879
Electric customer credits	(39,738)		244			(39,494)
Operating revenue, net	$	528,143	$	256,852		$	784,995
Net income	$	45,846	$	66,975		$	112,821
Add: Depreciation and amortization	83,009		23,991		(2)	107,000
Less: Interest income	1,468		6			1,474
Add: Interest charges	36,883		(332)			36,551
Add: Federal and state income tax (benefit) expense	(767)		22,673			21,906
EBITDA	$	163,503	$	113,301		$	276,804
Additions to property, plant, and equipment	$	134,185	$	4,882		$	139,067
Equity investment in investees (1)	$	5,572	$	—		$	5,572
Goodwill (1)	$	1,490,797	$	—		$	1,490,797
Total segment assets (1)	$	6,438,218	$	1,078,534		$	7,516,752
(1) Balances as of June 30, 2021. (2) Includes $6.4 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(4.6) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2021 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	723,021	$	(4,840)		$	—	$	718,181
Other operations	98,589		2			(3,535)		95,056
Affiliate revenue	2,879		53,276			(56,155)		—
Electric customer credits	(39,494)		—			—		(39,494)
Operating revenue, net	$	784,995	$	48,438		$	(59,690)	$	773,743
Depreciation and amortization	$	107,000	$	8,862	(2)	$	—	$	115,862
Interest income	$	1,474	$	57		$	(56)	$	1,475
Interest charges	$	36,551	$	30,687		$	(55)	$	67,183
Federal and state income tax expense (benefit)	$	21,906	$	(21,490)		$	—	$	416
Net income (loss)	$	112,821	$	(13,672)		$	—	$	99,149
Additions to property, plant, and equipment	$	139,067	$	1,440		$	—	$	140,507
Equity investment in investees (1)	$	5,572	$	—		$	—	$	5,572
Goodwill (1)	$	1,490,797	$	—		$	—	$	1,490,797
Total segment assets (1)	$	7,516,752	$	569,126		$	(144,409)	$	7,941,469
(1) Balances as of June 30, 2021. (2) Includes $4.8 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

2020 (THOUSANDS)	CLECO POWER		CLECO CAJUN			TOTAL SEGMENTS
Revenue
Electric operations	$	464,073	$	173,880		$	637,953
Other operations	31,668		61,597			93,265
Affiliate revenue	2,346		204			2,550
Electric customer credits	(17,440)		(153)			(17,593)
Operating revenue, net	$	480,647	$	235,528		$	716,175
Net income	$	40,064	$	46,298		$	86,362
Add: Depreciation and amortization	85,273		22,041		(2)	107,314
Less: Interest income	1,709		258			1,967
Add: Interest charges	37,184		131			37,315
Add: Federal and state income tax expense	12,694		15,022			27,716
EBITDA	$	173,506	$	83,234		$	256,740
Additions to property, plant, and equipment	$	132,578	$	5,417		$	137,995
Equity investment in investees (1)	$	9,072	$	—		$	9,072
Goodwill (1)	$	1,490,797	$	—		$	1,490,797
Total segment assets (1)	$	6,256,944	$	1,029,812		$	7,286,756
(1) Balances as of December 31, 2020. (2) Includes $6.2 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(4.6) million deferred lease revenue amortization as a result of the Cleco Cajun Transaction.

2020 (THOUSANDS)	TOTAL SEGMENTS		OTHER			ELIMINATIONS		TOTAL
Revenue
Electric operations	$	637,953	$	(4,840)		$	—	$	633,113
Other operations	93,265		1			(3,456)		89,810
Affiliate revenue	2,550		58,415			(60,965)		—
Electric customer credits	(17,593)		—			—		(17,593)
Operating revenue, net	$	716,175	$	53,576		$	(64,421)	$	705,330
Depreciation and amortization	$	107,314	$	9,079	(2)	$	—	$	116,393
Interest income	$	1,967	$	155		$	(68)	$	2,054
Interest charges	$	37,315	$	32,617		$	(69)	$	69,863
Federal and state income tax expense (benefit)	$	27,716	$	(12,561)		$	—	$	15,155
Net income (loss)	$	86,362	$	(36,865)		$	(1)	$	49,496
Additions to property, plant, and equipment	$	137,995	$	1,344		$	—	$	139,339
Equity investment in investees (1)	$	9,072	$	—		$	—	$	9,072
Goodwill (1)	$	1,490,797	$	—		$	—	$	1,490,797
Total segment assets (1)	$	7,286,756	$	595,217		$	(156,404)	$	7,725,569
(1) Balances as of December 31, 2020. (2) Includes $4.8 million of amortization of intangible assets related to Cleco Power’s wholesale power supply agreements as a result of the 2016 Merger.

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Net income	$	78,822	$	43,168	$	99,149	$	49,496
Add: Depreciation and amortization	57,699		57,304		115,862		116,393
Less: Interest income	829		898		1,475		2,054
Add: Interest charges	33,291		34,715		67,183		69,863
Add: Federal and state income tax expense	9,837		13,593		416		15,155
Add: Other corporate costs and noncash items (1)	(1,385)		(4,326)		(4,331)		7,887
Total segment EBITDA	$	177,435	$	143,556	$	276,804	$	256,740
(1) Adjustments made for Other and Elimination totals not allocated to total segment EBITDA.

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Regulation and Rates (Tables)

6 Months Ended

Jun. 30, 2021

Regulated Operations [Abstract]

Schedule of Provision of Rate Refund

Provision for rate refund on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets consisted primarily of the following:

(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
FRP	$	2,392	$	1,786
TCJA	$	2,057	$	2,057
Cleco Katrina/Rita storm recovery charges	$	1,610	$	1,617
Site-specific industrial customer	$	990	$	710
Transmission ROE	$	250	$	595
FERC audit	$	—	$	1,912

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Variable Interest Entities (Tables) - CLECO POWER

6 Months Ended

Jun. 30, 2021

Variable Interest Entity [Line Items]

Equity Method Investments

The following table presents the components of Cleco Power’s equity investment in Oxbow:

INCEPTION TO DATE (THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Purchase price	$	12,873	$	12,873
Cash contributions	6,399		6,399
Distributions	(13,700)		(10,200)
Total equity investment in investee	$	5,572	$	9,072

The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Operating revenue	$	1,627	$	29,110	$	3,626	$	30,991
Operating expenses	1,627		29,110		3,626		30,991
Income before taxes	$	—	$	—	$	—	$	—

Carrying Amount of Assets and Liabilities with Maximum Exposure to Loss

The following table compares the carrying amount of Oxbow’s assets and liabilities with Cleco Power’s maximum exposure to loss related to its investment in Oxbow:

(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Oxbow’s net assets/liabilities	$	11,145	$	18,145
Cleco Power’s 50% equity	$	5,572	$	9,072
Cleco Power’s maximum exposure to loss	$	5,572	$	9,072

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Affiliate Transactions (Tables)

6 Months Ended

Jun. 30, 2021

CLECO POWER

Related Party Transaction [Line Items]

Summary of Balances Payable To or Due From Affiliates

The following table is a summary of those balances:

	AT JUNE 30, 2021				AT DEC. 31, 2020
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	10,383	$	57,696	$	10,353	$	57,713
Support Group	1,707		12,737		3,248		14,355
Cleco Cajun	936		4		1,004		—
Total	$	13,026	$	70,437	$	14,605	$	72,068

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Intangible Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 2021

Finite-Lived Intangible Assets [Line Items]

Schedule of Amortization of Intangible Assets and Liabilities

The following tables present Cleco and Cleco Power’s amortization of intangible assets and liabilities:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Intangible assets
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	—	$	—	$	—	$	517
Trade name	$	64	$	64	$	128	$	128
Power supply agreements	$	6,400	$	6,400	$	12,800	$	12,800
Intangible liabilities
LTSA	$	871	$	871	$	1,742	$	1,742
Power supply agreements	$	718	$	882	$	1,600	$	1,764

Schedule of Finite-Lived Intangible Assets and Liabilities

The following tables summarize the balances for intangible assets and liabilities subject to amortization for Cleco:

Cleco
(THOUSANDS)	AT JUNE 30, 2021		AT DEC. 31, 2020
Intangible assets
Trade name	$	5,100	$	5,100
Power supply agreements	184,004		184,004
Total intangible assets carrying amount	189,104		189,104
Intangible liabilities
LTSA	24,100		24,100
Power supply agreements	14,200		14,200
Total intangible liability carrying amount	38,300		38,300
Net intangible assets carrying amount	150,804		150,804
Accumulated amortization	(73,517)		(63,932)
Net intangible assets subject to amortization	$	77,287	$	86,872

CLECO POWER

Finite-Lived Intangible Assets [Line Items]

Schedule of Amortization of Intangible Assets and Liabilities

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2021		2020		2021		2020
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	—	$	—	$	—	$	517

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Accumulated Other Comprehensive Loss (Tables)

6 Months Ended

Jun. 30, 2021

Accumulated Other Comprehensive Loss [Line Items]

Schedule of Accumulated Other Comprehensive Income Loss

The components of accumulated other comprehensive loss are summarized in the following tables for Cleco and Cleco Power. All amounts are reported net of income taxes. Amounts in parentheses indicate debits.

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30, 2021		FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(25,168)	$	(25,796)
Amounts reclassified from AOCI
Amortization of postretirement benefit net (gain) loss	(420)		208
Balances, June 30, 2021	$	(25,588)	$	(25,588)

	FOR THE THREE MONTHS ENDED JUNE 30, 2020		FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(17,099)	$	(17,513)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	442		856
Balances, June 30, 2020	$	(16,657)	$	(16,657)

CLECO POWER

Accumulated Other Comprehensive Loss [Line Items]

Schedule of Accumulated Other Comprehensive Income Loss

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2021						FOR THE SIX MONTHS ENDED JUNE 30, 2021
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI		POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(18,681)	$	(5,550)	$	(24,231)	$	(19,139)	$	(5,614)	$	(24,753)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	287		—		287		745		—		745
Reclassification of net loss to interest charges	—		64		64		—		128		128
Balances, June 30, 2021	$	(18,394)	$	(5,486)	$	(23,880)	$	(18,394)	$	(5,486)	$	(23,880)

	FOR THE THREE MONTHS ENDED JUNE 30, 2020						FOR THE SIX MONTHS ENDED JUNE 30, 2020
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI		POSTRETIREMENT BENEFIT NET LOSS		NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(16,291)	$	(5,804)	$	(22,095)	$	(16,717)	$	(5,868)	$	(22,585)
Amounts reclassified from AOCI
Amortization of postretirement benefit net loss	419		—		419		845		—		845
Reclassification of net loss to interest charges	—		64		64		—		128		128
Balances, June 30, 2020	$	(15,872)	$	(5,740)	$	(21,612)	$	(15,872)	$	(5,740)	$	(21,612)

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Summary of Significant Accounting Policies - Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Restricted Cash and Cash Equivalents Items [Line Items]
Current	$ 2,949	$ 4,545
Non-current	744	744
Total restricted cash and cash equivalents	3,693	5,289
Remaining restricted cash to be used for final administration and winding up activities	1,700
CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	2,949	4,545
Total restricted cash and cash equivalents	2,949	4,545
Cleco Katrina/Rita’s storm recovery bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,673	2,626
Cleco Katrina/Rita’s storm recovery bonds | CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,673	2,626
Charitable contributions
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,078	1,718
Charitable contributions | CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,078	1,718
Rate credit escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Current	198	201
Rate credit escrow | CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	198	201
Diversified Lands’ mitigation escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Non-current	22	22
Cleco Cajun’s defense fund
Restricted Cash and Cash Equivalents Items [Line Items]
Non-current	$ 722	$ 722

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Summary of Significant Accounting Policies - Changes in Allowance for Credit Losses (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Financing Receivable, Allowance for Credit Loss [Line Items]
Receivable, threshold period past due	20 days		20 days
ACCOUNTS RECEIVABLE
Accounts receivable, beginning balance	$ 2,040	$ 2,123	$ 2,758	$ 3,005
Current period provision	616	1,137	2,490	3,634
Charge-offs	(1,583)	0	(4,442)	(4,091)
Recovery	261	226	528	867
Accounts receivable, ending balance	1,334	3,486	1,334	3,486
OTHER
Financing receivable, beginning balance	1,638	1,638	1,638	1,250
Current period provision	0	0	0	388
Charge-offs	0	0	0	0
Recovery	0	0	0	0
Financing receivable, ending balance	1,638	1,638	1,638	1,638
Receivable, Allowance For Credit Loss [Roll Forward]
Total, beginning balance	3,678	3,761	4,396	4,255
Current period provision	616	1,137	2,490	4,022
Charge-offs	(1,583)	0	(4,442)	(4,091)
Recovery	261	226	528	867
Total, ending balance	2,972	5,124	2,972	5,124
CLECO POWER
ACCOUNTS RECEIVABLE
Accounts receivable, beginning balance	2,040	2,123	2,758	3,005
Current period provision	616	1,137	2,490	3,634
Charge-offs	(1,583)	0	(4,442)	(4,091)
Recovery	261	226	528	867
Accounts receivable, ending balance	$ 1,334	3,486	$ 1,334	3,486
Accounting Standards Update 2016-13 | CECL adoption
ACCOUNTS RECEIVABLE
Accounts receivable, beginning balance		0		71
Receivable, Allowance For Credit Loss [Roll Forward]
Total, beginning balance		0		71
Accounting Standards Update 2016-13 | CLECO POWER | CECL adoption
ACCOUNTS RECEIVABLE
Accounts receivable, beginning balance		0
Accounts receivable, ending balance		$ 71		$ 71

XML

Leases - Narrative (Details) $ in Millions	Jun. 30, 2021 USD ($)
Cottonwood Energy
Lessor, Lease, Description [Line Items]
Fixed lease payments per year	$ 40.0

XML

Leases - Lease Income Under Cottonwood Sale Leaseback (Details) - Cleco Cajun - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Lessor, Lease, Description [Line Items]
Fixed payments	$ 10,000	$ 10,000	$ 20,000	$ 20,000
Variable payments	5,010	5,194	10,475	10,760
Amortization of deferred lease liability	2,301	2,301	4,603	4,603
Total lease income	$ 17,311	$ 17,495	$ 35,078	$ 35,363

XML

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 359,657	$ 338,399	$ 729,774	$ 666,688
Revenue unrelated to contracts with customers
Other	19,092	19,359	43,969	38,642
Total revenue unrelated to contracts with customers	19,092	19,359	43,969	38,642
Operating revenue, net	378,749	357,758	773,743	705,330
Electric customer credits	18,517	9,100	39,494	17,593
Deferred lease amortization			4,603	4,603
Total retail revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	195,914	183,674	373,281	356,129
Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	105,315	97,973	200,396	179,544
Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	68,392	61,575	131,418	122,685
Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	37,385	29,208	74,051	61,418
Other retail
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3,876	3,341	7,446	6,802
Surcharge
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers				2,443
Electric customer credits
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(19,054)	(8,423)	(40,030)	(16,763)
Wholesale, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	135,203	128,007	296,012	256,963
Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	25,291	23,117	52,590	46,300
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3,249	3,601	7,891	7,296
Affiliate
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
CLECO CAJUN
Revenue unrelated to contracts with customers
Lease revenue		15,200	30,500	30,800
Deferred lease amortization	2,300	2,300	4,600	4,600
OPERATING SEGMENTS
Revenue unrelated to contracts with customers
Operating revenue, net	383,985	363,099	784,995	716,175
Electric customer credits	18,518	9,100	39,494	17,593
OPERATING SEGMENTS | CLECO POWER
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	259,916	245,834	519,284	477,388
Revenue unrelated to contracts with customers
Other	1,763	1,853	8,859	3,259
Total revenue unrelated to contracts with customers	1,763	1,853	8,859	3,259
Operating revenue, net	261,679	247,687	528,143	480,647
Electric customer credits	18,762	9,100	39,738	17,440
OPERATING SEGMENTS | CLECO POWER | Total retail revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	195,914	183,674	373,281	356,129
OPERATING SEGMENTS | CLECO POWER | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	105,315	97,973	200,396	179,544
OPERATING SEGMENTS | CLECO POWER | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	68,392	61,575	131,418	122,685
OPERATING SEGMENTS | CLECO POWER | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	37,385	29,208	74,051	61,418
OPERATING SEGMENTS | CLECO POWER | Other retail
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3,876	3,341	7,446	6,802
OPERATING SEGMENTS | CLECO POWER | Surcharge
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers				2,443
OPERATING SEGMENTS | CLECO POWER | Electric customer credits
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(19,054)	(8,423)	(40,030)	(16,763)
OPERATING SEGMENTS | CLECO POWER | Wholesale, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	46,216	45,694	107,938	87,923
OPERATING SEGMENTS | CLECO POWER | Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	13,313	11,625	27,295	23,694
Revenue unrelated to contracts with customers
Electric customer credits	300	700	300	700
OPERATING SEGMENTS | CLECO POWER | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3,249	3,601	7,891	7,296
OPERATING SEGMENTS | CLECO POWER | Affiliate
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,224	1,240	2,879	2,346
OPERATING SEGMENTS | CLECO CAJUN
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	104,980	97,907	221,744	200,146
Revenue unrelated to contracts with customers
Other	17,326	17,505	35,108	35,382
Total revenue unrelated to contracts with customers	17,326	17,505	35,108	35,382
Operating revenue, net	122,306	115,412	256,852	235,528
Electric customer credits	(244)	0	(244)	153
Lease revenue	15,000
OPERATING SEGMENTS | CLECO CAJUN | Total retail revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OPERATING SEGMENTS | CLECO CAJUN | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OPERATING SEGMENTS | CLECO CAJUN | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OPERATING SEGMENTS | CLECO CAJUN | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OPERATING SEGMENTS | CLECO CAJUN | Other retail
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OPERATING SEGMENTS | CLECO CAJUN | Surcharge
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers				0
OPERATING SEGMENTS | CLECO CAJUN | Electric customer credits
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OPERATING SEGMENTS | CLECO CAJUN | Wholesale, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	91,407	84,733	192,914	173,880
OPERATING SEGMENTS | CLECO CAJUN | Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	13,573	13,131	28,830	26,062
Revenue unrelated to contracts with customers
Electric customer credits	200		200	200
OPERATING SEGMENTS | CLECO CAJUN | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OPERATING SEGMENTS | CLECO CAJUN | Affiliate
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	43	0	204
OTHER
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	23,700	26,718	48,436	53,575
Revenue unrelated to contracts with customers
Other	1	1	2	1
Total revenue unrelated to contracts with customers	1	1	2	1
Operating revenue, net	23,701	26,719	48,438	53,576
Electric customer credits	0	0	0	0
OTHER | Total retail revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OTHER | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OTHER | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OTHER | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OTHER | Other retail
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OTHER | Surcharge
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers				0
OTHER | Electric customer credits
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OTHER | Wholesale, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(2,420)	(2,420)	(4,840)	(4,840)
OTHER | Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OTHER | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
OTHER | Affiliate
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	26,120	29,138	53,276	58,415
ELIMINATIONS
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(28,939)	(32,060)	(59,690)	(64,421)
Revenue unrelated to contracts with customers
Other	2	0	0	0
Total revenue unrelated to contracts with customers	2	0	0	0
Operating revenue, net	(28,937)	(32,060)	(59,690)	(64,421)
Electric customer credits	(1)	0	0	0
ELIMINATIONS | Total retail revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ELIMINATIONS | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ELIMINATIONS | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ELIMINATIONS | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ELIMINATIONS | Other retail
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ELIMINATIONS | Surcharge
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers				0
ELIMINATIONS | Electric customer credits
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ELIMINATIONS | Wholesale, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0	0	0
ELIMINATIONS | Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(1,595)	(1,639)	(3,535)	(3,456)
ELIMINATIONS | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	0	0
ELIMINATIONS | Affiliate
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ (27,344)	$ (30,421)	$ (56,155)	$ (60,965)

XML

Revenue Recognition - Narrative (Details) $ in Millions	Jun. 30, 2021 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied performance obligations	$ 68.2
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-07-01 | Minimum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied performance obligation durations	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-07-01 | Maximum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied performance obligation durations	14 years

XML

Regulatory Assets and Liabilities - Schedule of Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Jun. 16, 2021	Dec. 31, 2020
Regulatory Assets [Line Items]
Total regulatory assets, net	$ 572,751		$ 423,279
Financing costs
Regulatory Assets [Line Items]
Regulatory assets	7,419		7,592
Postretirement costs
Regulatory Assets [Line Items]
Regulatory assets	14,418		15,411
Fair value of long-term debt
Regulatory Assets [Line Items]
Regulatory assets	115,852		119,553
Debt issuance costs
Regulatory Assets [Line Items]
Regulatory assets	5,086		5,254
CLECO POWER
Regulatory Assets [Line Items]
Regulatory assets	583,746		456,034
Regulatory liabilities	(153,770)		(180,565)
Total regulatory assets, net	429,976		275,469
CLECO POWER | Acquisition/ transaction costs
Regulatory Assets [Line Items]
Regulatory assets	1,966		2,019
CLECO POWER | Acquisition/ transaction costs | Coughlin transaction costs
Regulatory Assets [Line Items]
Regulatory assets	861		876
CLECO POWER | Accumulated deferred fuel
Regulatory Assets [Line Items]
Regulatory assets	75,295		28,194
CLECO POWER | AFUDC equity gross-up
Regulatory Assets [Line Items]
Regulatory assets	68,122		69,670
CLECO POWER | Affordability study
Regulatory Assets [Line Items]
Regulatory assets	13,644	$ 13,600	0
CLECO POWER | AMI deferred revenue requirement
Regulatory Assets [Line Items]
Regulatory assets	2,318		2,591
CLECO POWER | AROs
Regulatory Assets [Line Items]
Regulatory assets	7,202		5,488
CLECO POWER | COVID-19 executive order
Regulatory Assets [Line Items]
Regulatory assets	2,953		2,953
CLECO POWER | Deferred storm restoration costs - Hurricane Delta
Regulatory Assets [Line Items]
Regulatory assets	17,802		17,051
CLECO POWER | Hurricane Laura
Regulatory Assets [Line Items]
Regulatory assets	56,412		54,406
CLECO POWER | Deferred storm restoration costs - Hurricane Zeta
Regulatory Assets [Line Items]
Regulatory assets	3,494		3,493
CLECO POWER | Deferred storm restoration costs - Winter Storms Uri & Viola
Regulatory Assets [Line Items]
Regulatory assets	1,980		0
CLECO POWER | Station closure costs | Dolet Hills
Regulatory Assets [Line Items]
Regulatory assets	91,479		48,982
CLECO POWER | Mine closure costs | Dolet Hills
Regulatory Assets [Line Items]
Regulatory assets	13,910		0
CLECO POWER | Emergency declarations
Regulatory Assets [Line Items]
Regulatory assets	0		270
CLECO POWER | Energy efficiency
Regulatory Assets [Line Items]
Regulatory assets	2,350		2,820
CLECO POWER | Financing costs
Regulatory Assets [Line Items]
Regulatory assets	7,011		7,184
CLECO POWER | Interest costs
Regulatory Assets [Line Items]
Regulatory assets	3,583		3,708
CLECO POWER | Madison Unit 3 property taxes
Regulatory Assets [Line Items]
Regulatory assets	4,181		0
CLECO POWER | Non-service cost of postretirement benefits
Regulatory Assets [Line Items]
Regulatory assets	10,881		9,901
CLECO POWER | Other
Regulatory Assets [Line Items]
Regulatory assets	13,040		4,229
CLECO POWER | Postretirement costs
Regulatory Assets [Line Items]
Regulatory assets	155,067		165,437
CLECO POWER | Production operations and maintenance expenses
Regulatory Assets [Line Items]
Regulatory assets	2,664		4,058
CLECO POWER | Rodemacher Unit 2 deferred costs | Rodemacher Unit 2 deferred costs
Regulatory Assets [Line Items]
Regulatory assets	4,115		1,333
CLECO POWER | St. Mary Clean Energy Center
Regulatory Assets [Line Items]
Regulatory assets	6,959		3,479
CLECO POWER | Training costs
Regulatory Assets [Line Items]
Regulatory assets	6,007		6,085
CLECO POWER | Tree trimming costs
Regulatory Assets [Line Items]
Regulatory assets	10,450		11,807
CLECO POWER | AFUDC
Regulatory Assets [Line Items]
Regulatory liabilities	(5,359)		(4,218)
CLECO POWER | Corporate franchise tax, net
Regulatory Assets [Line Items]
Regulatory liabilities	0		(763)
CLECO POWER | Deferred taxes, net
Regulatory Assets [Line Items]
Regulatory liabilities	$ (148,411)		$ (175,584)

XML

Regulatory Assets and Liabilities - Narrative (Details) - CLECO POWER customer in Thousands, $ in Thousands			6 Months Ended
	Jun. 16, 2021 USD ($)	Mar. 29, 2021 USD ($)	Jun. 30, 2021 USD ($)	Feb. 17, 2021 customer	Feb. 14, 2021 customer	Dec. 31, 2020 USD ($)
Regulatory Liabilities [Line Items]
Regulatory assets			$ 583,746			$ 456,034
Affordability study
Regulatory Liabilities [Line Items]
Regulatory assets	$ 13,600		13,644			0
Regulatory asset, amortization period	10 years
Mine closure costs | Dolet Hills
Regulatory Liabilities [Line Items]
Regulatory assets			13,910			0
Madison Unit 3 property taxes
Regulatory Liabilities [Line Items]
Regulatory assets			$ 4,181			0
Regulatory asset, amortization period			12 months
Northlake Transmission Agreement, under collection
Regulatory Liabilities [Line Items]
Regulatory assets			$ 3,500
Regulatory asset, amortization period			12 months
Other deferred costs, primarily base rate case
Regulatory Liabilities [Line Items]
Regulatory assets			$ 4,100
Regulatory asset, amortization period			4 years
Coughlin Pipeline Project, deferred revenue
Regulatory Liabilities [Line Items]
Regulatory assets			$ 5,400
Regulatory asset, amortization period			4 years
St. Mary Clean Energy Center
Regulatory Liabilities [Line Items]
Regulatory assets			$ 6,959			$ 3,479
Regulatory asset, amortization period			4 years
Deferred storm restoration costs - Winter Storms Uri & Viola
Regulatory Liabilities [Line Items]
Capitalized storm restoration costs		$ 50,000	$ 8,400
Capitalized storm restoration costs, amortization period		12 months
Winter Storm Uri
Regulatory Liabilities [Line Items]
Number of customers affected with power outage | customer					11
Winter Storm Viola
Regulatory Liabilities [Line Items]
Number of customers affected with power outage | customer				43

XML

Fair Value Accounting - Carrying Value and Estimated Fair Value (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred debt issuance costs not included in the carrying value of long-term debt	$ 12,800	$ 13,400
CLECO POWER
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred debt issuance costs not included in the carrying value of long-term debt	6,900	7,000
CARRYING VALUE
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	3,226,952	3,230,500
CARRYING VALUE | CLECO POWER
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,495,101	1,494,947
FAIR VALUE
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	3,509,555	3,541,349
FAIR VALUE | CLECO POWER
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 1,772,243	$ 1,794,799

XML

Fair Value Accounting - Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis (Details) - Measured on a Recurring Basis - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Asset description
Institutional money market funds	$ 77,105	$ 86,001
Total assets	141,601	99,405
Liability description
Total liabilities	1,161	3,237
CLECO POWER
Asset description
Institutional money market funds	19,061	25,357
Total assets	25,928	29,694
Liability description
Total liabilities	877	1,121
FTRs
Asset description
FTRs and other commodity derivatives	8,662	4,805
Liability description
FTRs and other commodity derivatives	1,161	1,625
FTRs | CLECO POWER
Asset description
FTRs and other commodity derivatives	6,867	4,337
Liability description
FTRs and other commodity derivatives	877	1,121
Other commodity derivatives
Asset description
FTRs and other commodity derivatives	55,834	8,599
Liability description
FTRs and other commodity derivatives	0	1,612
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)
Asset description
Institutional money market funds	0	0
Total assets	0	0
Liability description
Total liabilities	0	0
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | CLECO POWER
Asset description
Institutional money market funds	0	0
Total assets	0	0
Liability description
Total liabilities	0	0
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | FTRs
Asset description
FTRs and other commodity derivatives	0	0
Liability description
FTRs and other commodity derivatives	0	0
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | FTRs | CLECO POWER
Asset description
FTRs and other commodity derivatives	0	0
Liability description
FTRs and other commodity derivatives	0	0
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | Other commodity derivatives
Asset description
FTRs and other commodity derivatives	0	0
Liability description
FTRs and other commodity derivatives	0	0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)
Asset description
Institutional money market funds	77,105	86,001
Total assets	132,939	94,600
Liability description
Total liabilities	0	1,612
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | CLECO POWER
Asset description
Institutional money market funds	19,061	25,357
Total assets	19,061	25,357
Liability description
Total liabilities	0	0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | FTRs
Asset description
FTRs and other commodity derivatives	0	0
Liability description
FTRs and other commodity derivatives	0	0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | FTRs | CLECO POWER
Asset description
FTRs and other commodity derivatives	0	0
Liability description
FTRs and other commodity derivatives	0	0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | Other commodity derivatives
Asset description
FTRs and other commodity derivatives	55,834	8,599
Liability description
FTRs and other commodity derivatives	0	1,612
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset description
Institutional money market funds	0	0
FTRs and other commodity derivatives	8,662	4,805
Total assets	8,662	4,805
Liability description
FTRs and other commodity derivatives	1,161	1,625
Total liabilities	1,161	1,625
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | CLECO POWER
Asset description
Institutional money market funds	0	0
FTRs and other commodity derivatives	6,867	4,337
Total assets	6,867	4,337
Liability description
FTRs and other commodity derivatives	877	1,121
Total liabilities	877	1,121
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | FTRs
Asset description
FTRs and other commodity derivatives	8,662	4,805
Liability description
FTRs and other commodity derivatives	1,161	1,625
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | FTRs | CLECO POWER
Asset description
FTRs and other commodity derivatives	6,867	4,337
Liability description
FTRs and other commodity derivatives	877	1,121
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | Other commodity derivatives
Asset description
FTRs and other commodity derivatives	0	0
Liability description
FTRs and other commodity derivatives	$ 0	$ 0

XML

Fair Value Accounting - Net Changes in Net Fair Value of FTR Assets and Liabilities Classified as Level 3 (Details) - Commodity-related contracts - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 1,023	$ 1,096	$ 3,180	$ 5,778
Unrealized gains (losses)	(1,005)	(284)	15,155	(371)
Purchases	9,958	9,267	10,806	9,732
Settlements	(2,475)	(2,039)	(21,640)	(7,099)
Ending balance	7,501	8,040	7,501	8,040
CLECO POWER
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	1,088	1,149	3,216	5,725
Unrealized gains (losses)	(402)	1,298	(402)	1,298
Purchases	7,768	7,311	8,616	7,776
Settlements	(2,464)	(2,247)	(5,440)	(7,288)
Ending balance	$ 5,990	$ 7,511	$ 5,990	$ 7,511

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Fair Value Accounting - Significant Unobservable Inputs Used in Developing Fair Value of Level 3 Positions (Details) - Measured on a Recurring Basis - Level 3 $ in Thousands	Jun. 30, 2021 USD ($) $ / MW	Dec. 31, 2020 USD ($) $ / MW
FAIR VALUE
ASSETS | $	$ 8,662	$ 4,805
LIABILITIES | $	1,161	1,625
CLECO POWER
FAIR VALUE
ASSETS | $	6,867	4,337
LIABILITIES | $	$ 877	$ 1,121
Minimum
FAIR VALUE
FORWARD PRICE RANGE (usd per mwh) | $ / MW	(5.73)	(3.49)
Minimum | CLECO POWER
FAIR VALUE
FORWARD PRICE RANGE (usd per mwh) | $ / MW	(2.03)	(3.34)
Maximum
FAIR VALUE
FORWARD PRICE RANGE (usd per mwh) | $ / MW	7.28	4.36
Maximum | CLECO POWER
FAIR VALUE
FORWARD PRICE RANGE (usd per mwh) | $ / MW	7.28	4.36

XML

Fair Value Accounting - Institutional Money Market Funds (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 73,412	$ 80,712
CLECO POWER
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Cash and cash equivalents	16,112	20,812
Current restricted cash and cash equivalents
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Restricted cash and cash equivalents	2,949	4,545
Current restricted cash and cash equivalents | CLECO POWER
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Restricted cash and cash equivalents	2,949	4,545
Non-current restricted cash and cash equivalents
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Restricted cash and cash equivalents	$ 744	$ 744

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Fair Value Accounting - Fair Value of Derivative Instruments as Recorded in Condensed Consolidated Balance Sheets (Details) - DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Commodity-related contracts
Commodity-related contracts, net	$ 63,335	$ 10,167
Commodity-related contracts | CLECO POWER
Commodity-related contracts
Commodity-related contracts, net	5,990	3,216
Commodity-related contracts | Energy risk management assets
Commodity-related contracts
Derivative asset	8,662	4,805
Commodity-related contracts | Energy risk management assets | CLECO POWER
Commodity-related contracts
Derivative asset	6,867	4,337
Commodity-related contracts | Energy risk management liabilities
Commodity-related contracts
Derivative liability	(1,161)	(1,625)
Commodity-related contracts | Energy risk management liabilities | CLECO POWER
Commodity-related contracts
Derivative liability	(877)	(1,121)
Other commodity derivatives | Energy risk management assets
Commodity-related contracts
Derivative asset	30,063	8,276
Other commodity derivatives | Energy risk management liabilities
Commodity-related contracts
Derivative liability	0	(828)
Other commodity derivatives | Other deferred charges
Commodity-related contracts
Derivative asset	25,771	323
Other commodity derivatives | Other deferred credits
Commodity-related contracts
Derivative liability	$ 0	$ (784)

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Fair Value Accounting - Amount of Gain (Loss) Recognized in Income on Derivatives (Details) - DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS - Commodity-related contracts - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	$ (49,218)	$ 11,260	$ (56,548)	$ 5,167
Accumulated deferred fuel
Commodity-related contracts
Unrealized gains (losses) associated with FTRs	(400)	(1,300)	(400)	(1,300)
CLECO POWER
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	530	533	794	1,179
CLECO POWER | Accumulated deferred fuel
Commodity-related contracts
Unrealized gains (losses) associated with FTRs	(400)	(1,300)	(400)	(1,300)
Electric operations
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	1,763	1,852	9,207	3,248
Electric operations | CLECO POWER
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	1,763	1,852	9,208	3,249
Purchased power
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	702	92	(7,858)	(289)
Purchased power | CLECO POWER
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	(1,233)	(1,319)	(8,414)	(2,070)
Fuel used for electric generation
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	$ (51,683)	$ 9,316	$ (57,897)	$ 2,208

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Fair Value Accounting - Narrative (Details) MWh in Millions, MMBTU in Millions	6 Months Ended		12 Months Ended
	Jun. 30, 2021 MWh	Jun. 30, 2021 MMBTU	Dec. 31, 2020 MWh	Dec. 31, 2020 MMBTU
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Volume outstanding	30.9	127.9	15.3	73.0
CLECO POWER
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Volume outstanding	19.8		9.5

XML

Debt (Details)		6 Months Ended
	May 21, 2021 USD ($)	Jun. 30, 2021 USD ($)
Line of credit | Revolving credit agreement
Debt [Line Items]
Debt, face amount	$ 175,000,000.0
Ratio of indebtedness	0.65
Commitment fees	0.275%
Potential additional interest	0.175%
Borrowings outstanding		$ 0
Term loan
Debt [Line Items]
Debt, face amount	$ 266,000,000.0
LIBOR | Line of credit | Revolving credit agreement
Debt [Line Items]
Basis spread on variable rate	1.625%
LIBOR | Term loan
Debt [Line Items]
Basis spread on variable rate	1.625%
ABR | Line of credit | Revolving credit agreement
Debt [Line Items]
Basis spread on variable rate	0.625%
ABR | Term loan
Debt [Line Items]
Basis spread on variable rate	0.625%
CLECO POWER | Line of credit | Revolving credit agreement
Debt [Line Items]
Debt, face amount	$ 300,000,000.0
Ratio of indebtedness	0.65
Commitment fees	0.15%
Potential additional interest	0.15%
Borrowings outstanding		$ 160,000,000.0
CLECO POWER | Term loan
Debt [Line Items]
Debt, face amount	$ 125,000,000.0
CLECO POWER | LIBOR | Line of credit | Revolving credit agreement
Debt [Line Items]
Basis spread on variable rate		1.25%
CLECO POWER | LIBOR | Term loan
Debt [Line Items]
Basis spread on variable rate	1.25%
CLECO POWER | ABR | Line of credit | Revolving credit agreement
Debt [Line Items]
Basis spread on variable rate		0.25%
CLECO POWER | ABR | Term loan
Debt [Line Items]
Basis spread on variable rate	0.25%

XML

Pension Plan and Employee Benefits - Narrative (Details) - USD ($)		3 Months Ended		6 Months Ended
	Mar. 11, 2021	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Pension contributions required through 2025	$ 0
Expected contributions in current year		$ 67,000,000.0		$ 67,000,000.0
Defined benefit plan contributions by employer		7,358,000	$ 6,080,000	13,561,000	$ 10,950,000
Pension Plan | Other Subsidiaries
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan contributions by employer		900,000	1,300,000	1,800,000	1,700,000
Other Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan contributions by employer		1,302,000	1,258,000	2,605,000	2,515,000
Assets held-in-trust, noncurrent		0		0
Other Benefits Plan | CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan contributions by employer		1,200,000	1,200,000	2,400,000	2,500,000
SERP
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan contributions by employer		249,000	1,607,000	1,891,000	3,151,000
SERP | CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan contributions by employer		$ 100,000	$ 200,000	$ 300,000	$ 500,000

XML

Pension Plan and Employee Benefits - Net Periodic Pension and Benefits Cost (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
PENSION BENEFITS
Components of periodic benefit costs
Service cost	$ 2,730	$ 2,582	$ 5,258	$ 4,910
Interest cost	4,719	5,278	9,334	10,408
Expected return on plan assets	(5,698)	(6,242)	(11,400)	(12,487)
Amortizations
Prior period service credit	0	(15)	0	(30)
Net loss	5,607	4,477	10,369	8,149
Net periodic benefit cost	7,358	6,080	13,561	10,950
OTHER BENEFITS
Components of periodic benefit costs
Service cost	595	508	1,190	1,015
Interest cost	323	410	645	820
Expected return on plan assets	0	0	0	0
Amortizations
Prior period service credit	0	0	0	0
Net loss	384	340	770	680
Net periodic benefit cost	1,302	1,258	2,605	2,515
SERP
Components of periodic benefit costs
Service cost	61	105	116	200
Interest cost	644	734	1,269	1,466
Amortizations
Prior period service credit	(55)	(67)	(107)	(107)
Net loss	(401)	835	613	1,592
Net periodic benefit cost	$ 249	$ 1,607	$ 1,891	$ 3,151

XML

Pension Plan and Employee Benefits - Current and Non-Current Portions of the Other Benefits Liability (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Non-current	$ 316,330	$ 314,653
CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Non-current	233,265	230,825
Other Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Current	4,463	4,463
Non-current	51,522	51,868
Other Benefits Plan | CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Current	3,865	3,865
Non-current	$ 40,449	$ 40,734

XML

Pension Plan and Employee Benefits - Current and Non-Current Portions of SERP Liability (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Non-current	$ 316,330	$ 314,653
SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Current	4,703	4,703
Non-current	91,355	92,522
CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Non-current	233,265	230,825
CLECO POWER | SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Current	711	711
Non-current	$ 19,364	$ 19,828

XML

Pension Plan and Employee Benefits - 401 (K) Plans (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense	$ 2,120	$ 1,898	$ 4,880	$ 5,154
Other Subsidiaries
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense	$ 946	$ 832	$ 2,326	$ 2,495

XML

Income Taxes - Effective Tax Rate Reconciliation (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
Effective Income Tax Rate [Line Items]
Effective tax rate	11.10%	23.90%	0.40%	23.40%
CLECO POWER
Effective Income Tax Rate [Line Items]
Effective tax rate	24.60%	24.90%	(1.70%)	24.10%

XML

Income Taxes - Narrative (Details) - USD ($)	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Uncertain Tax Positions [Line Items]
Liability for uncertain tax positions	$ 0		$ 0		$ 0
Interest payable related to uncertain tax positions	0		0		0
Penalties	0	$ 0	0	$ 0
Deferred employer payroll tax payments					6,000,000.0
Deferred employer payroll tax payments to be paid in 2021					3,000,000.0
Deferred employer payroll tax payments to be paid in 2022					3,000,000.0
CLECO POWER
Uncertain Tax Positions [Line Items]
Liability for uncertain tax positions	0		0		0
Interest payable related to uncertain tax positions	$ 0		$ 0		0
Deferred employer payroll tax payments					3,600,000
Deferred employer payroll tax payments to be paid in 2021					1,800,000
Deferred employer payroll tax payments to be paid in 2022					$ 1,800,000

XML

Disclosures about Segments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Revenue
Electric operations	$ 351,936	$ 321,956	$ 718,181	$ 633,113
Other operations	45,330	44,902	95,056	89,810
Affiliate revenue	0	0	0	0
Electric customer credits	(18,517)	(9,100)	(39,494)	(17,593)
Operating revenue, net	378,749	357,758	773,743	705,330
Net income	78,822	43,168	99,149	49,496
Depreciation and amortization	57,699	57,304	115,862	116,393
Interest income	829	898	1,475	2,054
Interest charges	33,291	34,715	67,183	69,863
Federal and state income tax (benefit)	9,837	13,593	416	15,155
Other corporate costs and noncash items	(1,385)	(4,326)	(4,331)	7,887
EBITDA	177,435	143,556	276,804	256,740
Additions to property, plant, and equipment			140,507	139,339
Equity investment in investees	5,572		5,572		$ 9,072
Goodwill	1,490,797		1,490,797		1,490,797
Total assets	7,941,469		7,941,469		7,725,569
CLECO POWER
Revenue
Electric operations	262,948	239,643	530,107	464,073
Other operations	16,269	15,904	34,895	31,668
Affiliate revenue	1,224	1,240	2,879	2,346
Electric customer credits	(18,762)	(9,100)	(39,738)	(17,440)
Operating revenue, net	261,679	247,687	528,143	480,647
Net income	27,421	28,233	45,846	40,064
Interest income	825	755	1,468	1,709
Interest charges	18,237	18,603	36,883	37,184
Federal and state income tax (benefit)	8,956	9,356	(767)	12,694
Additions to property, plant, and equipment			134,185	132,578
Equity investment in investees	5,572		5,572		9,072
Total assets	4,947,421		4,947,421		4,766,147
Power supply agreements
Revenue
Amortization of intangible assets	6,400	6,400	12,800	12,800
OPERATING SEGMENTS
Revenue
Electric operations	354,355	324,376	723,021	637,953
Other operations	46,924	46,540	98,589	93,265
Affiliate revenue	1,224	1,283	2,879	2,550
Electric customer credits	(18,518)	(9,100)	(39,494)	(17,593)
Operating revenue, net	383,985	363,099	784,995	716,175
Net income	79,915	54,995	112,821	86,362
Depreciation and amortization	53,272	52,739	107,000	107,314
Interest income	828	858	1,474	1,967
Interest charges	18,057	18,723	36,551	37,315
Federal and state income tax (benefit)	27,019	17,957	21,906	27,716
EBITDA	177,435	143,556	276,804	256,740
Additions to property, plant, and equipment			139,067	137,995
Equity investment in investees	5,572		5,572		9,072
Goodwill	1,490,797		1,490,797		1,490,797
Total assets	7,516,752		7,516,752		7,286,756
OPERATING SEGMENTS | CLECO POWER
Revenue
Electric operations	262,948	239,643	530,107	464,073
Other operations	16,269	15,904	34,895	31,668
Affiliate revenue	1,224	1,240	2,879	2,346
Electric customer credits	(18,762)	(9,100)	(39,738)	(17,440)
Operating revenue, net	261,679	247,687	528,143	480,647
Net income	27,421	28,233	45,846	40,064
Depreciation and amortization	40,933	41,596	83,009	85,273
Interest income	825	755	1,468	1,709
Interest charges	18,237	18,603	36,883	37,184
Federal and state income tax (benefit)	8,956	9,356	(767)	12,694
EBITDA	94,722	97,033	163,503	173,506
Additions to property, plant, and equipment			134,185	132,578
Equity investment in investees	5,572		5,572		9,072
Goodwill	1,490,797		1,490,797		1,490,797
Total assets	6,438,218		6,438,218		6,256,944
OPERATING SEGMENTS | CLECO CAJUN
Revenue
Electric operations	91,407	84,733	192,914	173,880
Other operations	30,655	30,636	63,694	61,597
Affiliate revenue	0	43	0	204
Electric customer credits	244	0	244	(153)
Operating revenue, net	122,306	115,412	256,852	235,528
Net income	52,494	26,762	66,975	46,298
Depreciation and amortization	12,339	11,143	23,991	22,041
Interest income	3	103	6	258
Interest charges	(180)	120	(332)	131
Federal and state income tax (benefit)	18,063	8,601	22,673	15,022
EBITDA	82,713	46,523	113,301	83,234
Additions to property, plant, and equipment			4,882	5,417
Equity investment in investees	0		0		0
Goodwill	0		0		0
Total assets	1,078,534		1,078,534		1,029,812
Amortization of deferred lease income	(2,300)	(2,300)	(4,600)	(4,600)
OPERATING SEGMENTS | CLECO CAJUN | Power supply agreements
Revenue
Amortization of intangible assets and liabilities	3,300	3,100	6,400	6,200
OTHER
Revenue
Electric operations	(2,420)	(2,420)	(4,840)	(4,840)
Other operations	1	1	2	1
Affiliate revenue	26,120	29,138	53,276	58,415
Electric customer credits	0	0	0	0
Operating revenue, net	23,701	26,719	48,438	53,576
Net income	(1,093)	(11,826)	(13,672)	(36,865)
Depreciation and amortization	4,427	4,565	8,862	9,079
Interest income	14	55	57	155
Interest charges	15,248	16,007	30,687	32,617
Federal and state income tax (benefit)	(17,182)	(4,364)	(21,490)	(12,561)
Additions to property, plant, and equipment			1,440	1,344
Equity investment in investees	0		0		0
Goodwill	0		0		0
Total assets	569,126		569,126		595,217
OTHER | Power supply agreements | CLECO POWER
Revenue
Amortization of intangible assets	2,400	2,400	4,800	4,800
ELIMINATIONS
Revenue
Electric operations	1	0	0	0
Other operations	(1,595)	(1,639)	(3,535)	(3,456)
Affiliate revenue	(27,344)	(30,421)	(56,155)	(60,965)
Electric customer credits	1	0	0	0
Operating revenue, net	(28,937)	(32,060)	(59,690)	(64,421)
Net income	0	(1)	0	(1)
Depreciation and amortization	0	0	0	0
Interest income	(13)	(15)	(56)	(68)
Interest charges	(14)	(15)	(55)	(69)
Federal and state income tax (benefit)	0	$ 0	0	0
Additions to property, plant, and equipment			0	$ 0
Equity investment in investees	0		0		0
Goodwill	0		0		0
Total assets	$ (144,409)		$ (144,409)		$ (156,404)

XML

Regulation and Rates - Provision for Rate Refund (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020	Jul. 31, 2019
Regulation and Rates [Line Items]
Provision for rate refund	$ 7,251	$ 9,444
FRP
Regulation and Rates [Line Items]
Provision for rate refund	2,392	1,786
TCJA
Regulation and Rates [Line Items]
Provision for rate refund	2,057	2,057
Cleco Katrina/Rita storm recovery charges
Regulation and Rates [Line Items]
Provision for rate refund	1,610	1,617
Site-specific industrial customer
Regulation and Rates [Line Items]
Provision for rate refund	990	710
Transmission ROE
Regulation and Rates [Line Items]
Provision for rate refund	250	595
FERC audit
Regulation and Rates [Line Items]
Provision for rate refund	0	1,912
CLECO POWER
Regulation and Rates [Line Items]
Provision for rate refund	7,251	8,630	$ 79,200
CLECO POWER | FRP
Regulation and Rates [Line Items]
Provision for rate refund	2,392	1,786
CLECO POWER | TCJA
Regulation and Rates [Line Items]
Provision for rate refund	2,057	2,057
CLECO POWER | Cleco Katrina/Rita storm recovery charges
Regulation and Rates [Line Items]
Provision for rate refund	1,610	1,617
CLECO POWER | Site-specific industrial customer
Regulation and Rates [Line Items]
Provision for rate refund	990	710
CLECO POWER | Transmission ROE
Regulation and Rates [Line Items]
Provision for rate refund	250	595
CLECO POWER | FERC audit
Regulation and Rates [Line Items]
Provision for rate refund	$ 0	$ 1,912

XML

Regulation and Rates - Narrative (Details) $ in Thousands			6 Months Ended
	Jul. 01, 2021	Jun. 16, 2021 USD ($)	Jun. 30, 2021 USD ($) complaint	Dec. 31, 2020 USD ($)	Nov. 13, 2020 USD ($)	Jul. 31, 2019 USD ($)
Regulation and Rates [Line Items]
Refund due to customers			$ 7,251	$ 9,444
Current regulatory liabilities			44,862	23,509
FRP
Regulation and Rates [Line Items]
Refund due to customers			2,392	1,786
Cleco Katrina/Rita storm recovery charges
Regulation and Rates [Line Items]
Refund due to customers			$ 1,610	1,617
FERC
Regulation and Rates [Line Items]
Number of complaints filed | complaint			2
CLECO POWER
Regulation and Rates [Line Items]
Refund due to customers			$ 7,251	8,630		$ 79,200
Regulatory liabilities			153,770	180,565
Current regulatory liabilities			44,862	23,509
CLECO POWER | FRP
Regulation and Rates [Line Items]
Refund due to customers			2,392	1,786
CLECO POWER | FRP, expected to refund September 2021
Regulation and Rates [Line Items]
Refund due to customers			1,200
CLECO POWER | FRP, expected to refund September 2022
Regulation and Rates [Line Items]
Refund due to customers			1,200
CLECO POWER | Cleco Katrina/Rita storm recovery charges
Regulation and Rates [Line Items]
Refund due to customers			1,610	$ 1,617
CLECO POWER | LPSC
Regulation and Rates [Line Items]
TCJA, bill credit per month					$ 7,000
Bill credit related to unprotected excess ADIT					4,400
Bill credit per month related to change in federal statutory tax rate					$ 2,600
Estimated refund for the tax-related benefits from the TCJA			2,100
CLECO POWER | LPSC | Merger Commitments, cost savings
Regulation and Rates [Line Items]
Regulatory liabilities			$ 4,300
CLECO POWER | LPSC | FRP
Regulation and Rates [Line Items]
Target ROE allowed by FRP			10.00%
Percentage of retail earnings within range to be returned to customers			60.00%
ROE for customer credit, low range			10.90%
ROE for customer credit, high range			11.75%
CLECO POWER | LPSC | FRP | Subsequent event
Regulation and Rates [Line Items]
Target ROE allowed by FRP	9.50%
Percentage of retail earnings within range to be returned to customers	60.00%
ROE for customer credit, low range	10.00%
ROE for customer credit, high range	10.50%
CLECO POWER | LPSC | FRP | Maximum
Regulation and Rates [Line Items]
Target ROE allowed by FRP			10.90%
CLECO POWER | LPSC | FRP | Maximum | Subsequent event
Regulation and Rates [Line Items]
Target ROE allowed by FRP	10.00%
CLECO POWER | LPSC | Excess ADIT
Regulation and Rates [Line Items]
Bill credit related to unprotected excess ADIT		$ 2,500
Regulatory liability, amortization period		3 years
Regulatory liabilities			$ 324,600
Current regulatory liabilities			39,500
CLECO POWER | FERC | Transmission return on equity
Regulation and Rates [Line Items]
Refund due to customers			$ 300

XML

Variable Interest Entities - Narrative (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Equity investment in investee	$ 5,572	$ 9,072
CLECO POWER
Variable Interest Entity [Line Items]
Equity investment in investee	5,572	$ 9,072
Equity investment, total return of capital	$ 3,500
CLECO POWER | Oxbow
Variable Interest Entity [Line Items]
Ownership percentage by Cleco Power	50.00%
SWEPCO | Oxbow
Variable Interest Entity [Line Items]
Ownership percentage by other parties	50.00%

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Variable Interest Entities - Equity Method Investments (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Total equity investment in investee	$ 5,572		$ 5,572		$ 9,072
Operating revenue, net	378,749	$ 357,758	773,743	$ 705,330
CLECO POWER
Schedule of Equity Method Investments [Line Items]
Purchase price	12,873		12,873		12,873
Cash contributions	6,399		6,399		6,399
Distributions	(13,700)		(13,700)		(10,200)
Total equity investment in investee	5,572		5,572		$ 9,072
Operating revenue, net	261,679	247,687	528,143	480,647
CLECO POWER | Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Operating revenue, net	1,627	29,110	3,626	30,991
Operating expenses	1,627	29,110	3,626	30,991
Income before taxes	$ 0	$ 0	$ 0	$ 0

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Variable Interest Entities - Carrying Amount of Assets and Liabilities with Maximum Exposure to Loss (Details) - CLECO POWER - Oxbow - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Oxbow’s net assets/liabilities	$ 11,145	$ 18,145
Cleco Power’s 50% equity	5,572	9,072
Cleco Power’s maximum exposure to loss	$ 5,572	$ 9,072
Ownership percentage by Cleco Power	50.00%

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation (Details) $ in Thousands				1 Months Ended						3 Months Ended		6 Months Ended		24 Months Ended	30 Months Ended
	Jun. 01, 2020	May 21, 2020	Jan. 01, 2020	Mar. 31, 2020 USD ($)	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2015 USD ($)	Dec. 31, 2014 claim	Nov. 30, 2014 claim	Jun. 30, 2021 USD ($)	Jun. 30, 2020 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2020 USD ($)	Dec. 31, 2019 USD ($)	May 31, 2016 complaint	Mar. 29, 2021 USD ($)	Sep. 27, 2019 recommendation finding	Dec. 31, 2017 USD ($)
Loss Contingencies [Line Items]
Electric customer credits										$ 18,517	$ 9,100	$ 39,494	$ 17,593
Loss contingency, estimate of possible loss										3,800		3,800
South Central Generating
Loss Contingencies [Line Items]
Loss contingency, estimate of possible loss										1,500		1,500
Indemnification asset																		$ 10,000
Contingent liability																		$ 10,000
FERC | MISO Transmission Rates
Loss Contingencies [Line Items]
Public utilities, requested rate increase (decrease), percentage (in hundredths)									0.50%
Gulf Coast Spinning start up costs
Loss Contingencies [Line Items]
Allegations by plaintiff, failure to perform							$ 6,500
Gulf Coast Spinning construction of cotton spinning facility
Loss Contingencies [Line Items]
Allegations by plaintiff, failure to perform							$ 60,000
Actions filed in the 9th Judicial District Court | Alleged Breach of Fiduciary Duties
Loss Contingencies [Line Items]
Number of actions filed | claim									4
Actions filed in the Civil District Court | Alleged Breach of Fiduciary Duties
Loss Contingencies [Line Items]
Number of actions filed | claim								3	3
CLECO POWER
Loss Contingencies [Line Items]
Electric customer credits										18,762	$ 9,100	39,738	$ 17,440
CLECO POWER | Deferred storm restoration costs - Winter Storms Uri & Viola
Loss Contingencies [Line Items]
Capitalized storm restoration costs										8,400		8,400				$ 50,000
CLECO POWER | LPSC 2018-2019 Fuel Audit
Loss Contingencies [Line Items]
Fuel expense														$ 565,800
CLECO POWER | MISO Transmission Rates
Loss Contingencies [Line Items]
Public utilities, proposed return on equity, percentage (in hundredths)	10.52%		10.38%		10.32%	9.70%
CLECO POWER | LPSC
Loss Contingencies [Line Items]
Environmental expense				$ 26,200
CLECO POWER | FERC
Loss Contingencies [Line Items]
Number of findings | finding																	12
Number of recommendations | recommendation																	59
Electric customer credits												4,400
Loss contingency, estimate of possible loss										$ 300		$ 300
CLECO POWER | FERC | MISO Transmission Rates
Loss Contingencies [Line Items]
Number of actions filed | complaint															2
Public utilities, approved return on equity, percentage (In hundredths)															12.38%
Public utilities, proposed return on equity, percentage (in hundredths)		10.02%			9.88%										6.68%

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Off-Balance Sheet Commitments and Guarantees (Details) - USD ($)	1 Months Ended	6 Months Ended
	Mar. 31, 2021	Jun. 30, 2021
Guarantor Obligations [Line Items]
Guarantor obligations, collateral held directly or by third parties, amount		$ 0
Performance Guarantee
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted		42,400,000
Indemnification Agreement
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted		40,000,000.0
Indemnification Agreement including fundamental organizational structure
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted		400,000,000.0
CLECO POWER
Guarantor Obligations [Line Items]
Guarantor obligations, collateral held directly or by third parties, amount		0
CLECO POWER | Letters of Credit | Deferred storm restoration costs - Winter Storms Uri & Viola
Guarantor Obligations [Line Items]
Collateral returned	$ 24,900,000
CLECO POWER | Indemnification Agreement
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted		40,000,000.0
CLECO POWER | Indemnification Agreement including fundamental organizational structure
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted		400,000,000.0
CLECO POWER | Financial Guarantee
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted		$ 25,000,000.0
Cleco Cajun | Letters of Credit | Deferred storm restoration costs - Winter Storms Uri & Viola
Guarantor Obligations [Line Items]
Collateral returned	$ 6,500,000

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Risks and Uncertainties (Details) - CLECO POWER - USD ($) $ in Millions	1 Months Ended
	Jun. 30, 2020	Jun. 30, 2021
Dolet Hills Power Station
Loss Contingencies [Line Items]
Increase in ARO liabilities	$ 3.3
Investment balance		$ 62.6
Dolet Hills Power Station | DHLC
Loss Contingencies [Line Items]
Costs to be billed		96.1
Oxbow | Oxbow
Loss Contingencies [Line Items]
Costs to be billed		$ 6.6

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Affiliate Transactions - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020	Dec. 31, 2020
Related Party Transaction [Line Items]
Accounts receivable - affiliate	$ 2,686		$ 2,686		$ 1,663
Accounts payable - affiliate	41,283		41,283		41,283
CLECO POWER
Related Party Transaction [Line Items]
Accounts receivable - affiliate	13,026		13,026		14,605
Accounts payable - affiliate	70,437		70,437		72,068
CLECO POWER | Cleco Holdings
Related Party Transaction [Line Items]
Accounts receivable - affiliate	10,383		10,383		10,353
Accounts payable - affiliate	57,696		57,696		57,713
CLECO POWER | Cleco Holdings | Settlement of taxes payable
Related Party Transaction [Line Items]
Accounts payable - affiliate	57,600		57,600		57,600
CLECO POWER | Affiliates
Related Party Transaction [Line Items]
Accounts receivable - affiliate	1,707		1,707		3,248
Accounts payable - affiliate	12,737		12,737		14,355
CLECO POWER | Oxbow | Affiliates
Related Party Transaction [Line Items]
Cost of mineral rights and land leases	900	$ 14,600	1,900	$ 15,500
Due to affiliates	$ 300		$ 300		$ 300

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Affiliate Transactions - Summary of Balances Payable To or Due From Affiliates (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	$ 2,686	$ 1,663
ACCOUNTS PAYABLE	41,283	41,283
CLECO POWER
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	13,026	14,605
ACCOUNTS PAYABLE	70,437	72,068
CLECO POWER | Cleco Holdings
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	10,383	10,353
ACCOUNTS PAYABLE	57,696	57,713
CLECO POWER | Support Group
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	1,707	3,248
ACCOUNTS PAYABLE	12,737	14,355
CLECO POWER | Cleco Cajun
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	936	1,004
ACCOUNTS PAYABLE	$ 4	$ 0

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Intangible Assets and Liabilities - Narrative (Details) - USD ($)	6 Months Ended	12 Months Ended
	Jun. 30, 2021	Dec. 31, 2008	Mar. 31, 2020
Trade name
Finite-Lived Intangible Assets [Line Items]
Intangible assets, residual value	$ 0
Finite-lived intangible asset, useful life	20 years
Power supply agreements | Minimum
Finite-Lived Intangible Assets [Line Items]
Finite-lived intangible asset, useful life	7 years
Power supply agreements | Maximum
Finite-Lived Intangible Assets [Line Items]
Finite-lived intangible asset, useful life	19 years
Cleco Katrina/Rita
Finite-Lived Intangible Assets [Line Items]
Intangible assets, residual value			$ 0
Cleco Katrina/Rita | Cleco Katrina/Rita right to bill and collect storm recovery charges
Finite-Lived Intangible Assets [Line Items]
Finite-lived intangible assets acquired		$ 177,500,000
Cleco Katrina/Rita | Cleco Katrina/Rita right to bill and collect storm recovery charges from customers, net of financing costs
Finite-Lived Intangible Assets [Line Items]
Finite-lived intangible assets acquired		176,000,000.0
Cleco Katrina/Rita | Financing costs
Finite-Lived Intangible Assets [Line Items]
Finite-lived intangible assets acquired		$ 1,500,000
Cleco Cajun | LTSA
Finite-Lived Intangible Assets [Line Items]
Intangible liabilities, remaining life	7 years
Cleco Cajun | Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Intangible assets, residual value	$ 0
Cleco Cajun | Power supply agreements | Minimum
Finite-Lived Intangible Assets [Line Items]
Intangible assets, remaining life	2 years
Cleco Cajun | Power supply agreements | Maximum
Finite-Lived Intangible Assets [Line Items]
Intangible assets, remaining life	8 years

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Intangible Assets and Liabilities - Schedule of Amortization of Intangible Assets and Liabilities (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
LTSA
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible liabilities	$ 871	$ 871	$ 1,742	$ 1,742
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible liabilities	718	882	1,600	1,764
Cleco Katrina/Rita right to bill and collect storm recovery charges
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	0	0	0	517
Cleco Katrina/Rita right to bill and collect storm recovery charges | CLECO POWER
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	0	0	0	517
Trade name
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	64	64	128	128
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 6,400	$ 6,400	$ 12,800	$ 12,800

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Intangible Assets and Liabilities - Schedule of Finite-Lived Intangible Assets and Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2021	Dec. 31, 2020
Finite-Lived Intangible Assets [Line Items]
Total intangible assets carrying amount	$ 189,104	$ 189,104
Total intangible liability carrying amount	38,300	38,300
Net intangible assets carrying amount	150,804	150,804
Accumulated amortization	(73,517)	(63,932)
Net intangible assets subject to amortization	77,287	86,872
LTSA
Finite-Lived Intangible Assets [Line Items]
Total intangible liability carrying amount	24,100	24,100
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Total intangible liability carrying amount	14,200	14,200
Trade name
Finite-Lived Intangible Assets [Line Items]
Total intangible assets carrying amount	5,100	5,100
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Total intangible assets carrying amount	$ 184,004	$ 184,004

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Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2021	Jun. 30, 2020	Jun. 30, 2021	Jun. 30, 2020
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	$ 2,777,978	$ 2,649,748	$ 2,757,023	$ 2,643,006
Balances, end of period	2,856,380	2,693,358	2,856,380	2,693,358
TOTAL AOCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(25,168)	(17,099)	(25,796)	(17,513)
Balances, end of period	(25,588)	(16,657)	(25,588)	(16,657)
POSTRETIREMENT BENEFIT NET LOSS
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(25,168)	(17,099)	(25,796)	(17,513)
Amounts reclassified from AOCI	(420)	442	208	856
Balances, end of period	(25,588)	(16,657)	(25,588)	(16,657)
CLECO POWER
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	1,826,826	1,725,713	1,807,879	1,713,392
Balances, end of period	1,854,598	1,754,429	1,854,598	1,754,429
CLECO POWER | TOTAL AOCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(24,231)	(22,095)	(24,753)	(22,585)
Balances, end of period	(23,880)	(21,612)	(23,880)	(21,612)
CLECO POWER | POSTRETIREMENT BENEFIT NET LOSS
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(18,681)	(16,291)	(19,139)	(16,717)
Amounts reclassified from AOCI	287	419	745	845
Balances, end of period	(18,394)	(15,872)	(18,394)	(15,872)
CLECO POWER | NET LOSS ON CASH FLOW HEDGES
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(5,550)	(5,804)	(5,614)	(5,868)
Amounts reclassified from AOCI	64	64	128	128
Balances, end of period	$ (5,486)	$ (5,740)	$ (5,486)	$ (5,740)

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Storm Restoration (Details) $ in Thousands			1 Months Ended	2 Months Ended	6 Months Ended
	May 19, 2021 USD ($)	Mar. 29, 2021 USD ($)	Mar. 31, 2021 USD ($)	Oct. 28, 2020 USD ($) hurricane	Jun. 30, 2021 USD ($)	Dec. 31, 2020 USD ($)
Hurricanes
Unusual or Infrequent Item, or Both [Line Items]
Capitalization percentage				63.00%
Capitalized storm restoration costs, interim storm recovery amount	$ 16,000
Deferred storm restoration costs - Winter Storms Uri & Viola
Unusual or Infrequent Item, or Both [Line Items]
Capitalization percentage					80.00%
CLECO POWER
Unusual or Infrequent Item, or Both [Line Items]
Regulatory assets					$ 583,746	$ 456,034
CLECO POWER | Hurricane Laura, Delta and Zeta
Unusual or Infrequent Item, or Both [Line Items]
Regulatory assets					77,700
CLECO POWER | Deferred storm restoration costs - Winter Storms Uri & Viola
Unusual or Infrequent Item, or Both [Line Items]
Regulatory assets					1,980	$ 0
CLECO POWER | Hurricanes
Unusual or Infrequent Item, or Both [Line Items]
Number of hurricanes | hurricane				3
Estimate of storm restoration costs				$ 243,000
Capitalized storm restoration costs				$ 152,400
CLECO POWER | Deferred storm restoration costs - Winter Storms Uri & Viola
Unusual or Infrequent Item, or Both [Line Items]
Estimate of storm restoration costs					10,500
Capitalized storm restoration costs		$ 50,000			8,400
Capitalized storm restoration costs, amortization period		12 months
Fuel and purchased power costs					55,000
CLECO POWER | Deferred storm restoration costs - Winter Storms Uri & Viola | Letters of Credit
Unusual or Infrequent Item, or Both [Line Items]
Collateral returned			$ 24,900
Cleco Cajun | Deferred storm restoration costs - Winter Storms Uri & Viola
Unusual or Infrequent Item, or Both [Line Items]
Fuel and purchased power costs					$ 11,200
Cleco Cajun | Deferred storm restoration costs - Winter Storms Uri & Viola | Letters of Credit
Unusual or Infrequent Item, or Both [Line Items]
Collateral returned			$ 6,500