Cleco Corporate 10-Q 5 Nov 21 2021 Q3 Quarterly report Financial data

Cover Page

Cover Page	9 Months Ended
	Sep. 30, 2021shares
Entity Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 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	Q3
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

Condensed Consolidated Statemen

Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Operating revenue
Electric operations	$ 462,164	$ 386,388	$ 1,180,345	$ 1,019,501
Other operations	55,721	47,597	150,777	137,407
Affiliate revenue	0	0	0	0
Gross operating revenue	517,885	433,985	1,331,122	1,156,908
Electric customer credits	(691)	(16,534)	(40,185)	(34,126)
Operating revenue, net	517,194	417,451	1,290,937	1,122,782
Operating expenses
Fuel used for electric generation	69,318	74,142	150,620	218,643
Purchased power	101,377	82,690	336,573	208,515
Other operations and maintenance	76,506	71,131	221,486	217,693
Depreciation and amortization	60,628	52,892	169,892	162,852
Taxes other than income taxes	17,766	14,660	50,769	45,233
Merger transaction and commitment costs	34	184	(252)	3,234
Total operating expenses	325,629	295,699	929,088	856,170
Operating income	191,565	121,752	361,849	266,612
Interest income	941	910	2,416	2,964
Allowance for equity funds used during construction	711	144	2,703	197
Other expense, net	(8,109)	(3,374)	(15,112)	(15,827)
Interest charges
Interest charges, net	35,174	34,349	103,092	104,700
Allowance for borrowed funds used during construction	(545)	(289)	(1,280)	(777)
Total interest charges	34,629	34,060	101,812	103,923
Income before income taxes	150,479	85,372	250,044	150,023
Federal and state income tax expense	30,569	25,075	30,985	40,230
Net income	119,910	60,297	219,059	109,793
CLECO POWER
Operating revenue
Electric operations	357,084	288,852	887,191	752,925
Other operations	22,779	17,775	57,674	49,443
Affiliate revenue	1,380	1,506	4,259	3,852
Gross operating revenue	381,243	308,133	949,124	806,220
Electric customer credits	(691)	(16,534)	(40,429)	(33,974)
Operating revenue, net	380,552	291,599	908,695	772,246
Operating expenses
Fuel used for electric generation	149,127	80,148	262,970	205,276
Purchased power	38,211	32,096	151,499	74,737
Other operations and maintenance	56,720	52,595	162,448	164,207
Depreciation and amortization	43,526	40,268	126,534	125,541
Taxes other than income taxes	12,891	11,408	36,707	33,132
Total operating expenses	300,475	216,515	740,158	602,893
Operating income	80,077	75,084	168,537	169,353
Interest income	936	789	2,404	2,498
Allowance for equity funds used during construction	711	144	2,703	197
Other expense, net	(6,106)	(3,408)	(16,064)	(9,498)
Interest charges
Interest charges, net	19,054	18,730	56,672	56,401
Allowance for borrowed funds used during construction	(545)	(289)	(1,280)	(777)
Total interest charges	18,509	18,441	55,392	55,624
Income before income taxes	57,109	54,168	102,188	106,926
Federal and state income tax expense	548	18,076	(219)	30,770
Net income	$ 56,561	$ 36,092	$ 102,407	$ 76,156

Condensed Consolidated Statem_2

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Net income	$ 119,910	$ 60,297	$ 219,059	$ 109,793
Other comprehensive income, net of tax
Postretirement benefits gain (loss), net of tax expense (benefit)	96	448	304	1,304
Total other comprehensive income (loss), net of tax	96	448	304	1,304
Comprehensive income, net of tax	120,006	60,745	219,363	111,097
CLECO POWER
Net income	56,561	36,092	102,407	76,156
Other comprehensive income, net of tax
Postretirement benefits gain (loss), net of tax expense (benefit)	350	373	1,095	1,218
Amortization of interest rate derivatives to earnings	63	63	191	191
Total other comprehensive income (loss), net of tax	413	436	1,286	1,409
Comprehensive income, net of tax	$ 56,974	$ 36,528	$ 103,693	$ 77,565

Condensed Consolidated Statem_3

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Tax (expense) benefit of postretirement benefits gain (loss)	$ (34)	$ (159)	$ (107)	$ (460)
CLECO POWER
Tax (expense) benefit of postretirement benefits gain (loss)	(123)	(132)	(386)	(430)
Tax expense on amortization of interest rate derivatives to earnings	$ 22	$ 22	$ 67	$ 67

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Current assets
Cash and cash equivalents	$ 273,215	$ 84,976
Restricted cash and cash equivalents	2,352	4,545
Customer accounts receivable (less allowance for credit losses)	114,412	82,511
Accounts receivable - affiliate	3,038	1,663
Other accounts receivable	45,887	32,076
Taxes receivable	5,336	0
Unbilled revenue	36,759	40,127
Fuel inventory, at average cost	112,016	109,494
Materials and supplies, at average cost	132,848	132,449
Energy risk management assets	58,803	13,081
Accumulated deferred fuel	78,847	28,194
Cash surrender value of company-/trust-owned life insurance policies	94,361	89,138
Prepayments	15,013	14,549
Regulatory assets	26,495	21,041
Other current assets	23,292	11,048
Total current assets	1,022,674	664,892
Property, plant, and equipment
Property, plant, and equipment	5,596,964	5,337,190
Accumulated depreciation	(887,107)	(672,271)
Net property, plant, and equipment	4,709,857	4,664,919
Construction work in progress	134,130	124,622
Total property, plant, and equipment, net	4,843,987	4,789,541
Equity investment in investee	3,822	9,072
Goodwill	1,490,797	1,490,797
Prepayments	19,974	23,405
Operating lease right of use assets	24,689	26,172
Restricted cash and cash equivalents	745	744
Note receivable	13,941	14,506
Regulatory assets	756,343	554,609
Intangible assets	88,635	111,731
Energy risk management assets	83,427	323
Other deferred charges	46,773	39,777
Total assets	8,395,807	7,725,569
Current liabilities
Short-term debt	0	75,000
Long-term debt and finance leases due within one year	66,736	66,682
Accounts payable	226,785	161,357
Accounts payable - affiliate	41,283	41,283
Customer deposits	60,186	58,718
Provision for rate refund	5,465	9,444
Taxes payable	47,095	7,530
Interest accrued	39,544	15,583
Energy risk management liabilities	1,589	2,453
Regulatory liabilities	46,003	23,509
Deferred compensation	13,695	13,240
Other current liabilities	60,507	49,813
Total current liabilities	608,888	524,612
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	734,717	661,376
Postretirement benefit obligations	320,504	314,653
Regulatory liabilities - deferred taxes, net	99,361	157,056
Deferred lease revenue	33,753	40,657
Intangible liabilities	20,257	24,859
Asset retirement obligations	71,390	27,986
Operating lease liabilities	21,739	23,333
Other deferred credits	25,008	28,627
Total long-term liabilities and deferred credits	1,326,729	1,278,547
Long-term debt and finance leases, net	3,483,804	3,165,387
Total liabilities	5,419,421	4,968,546
Commitments and contingencies (Note 13)
Member’s equity
Member’s equity	2,976,386	2,757,023
Total liabilities and member’s equity	8,395,807	7,725,569
CLECO POWER
Current assets
Cash and cash equivalents	156,318	24,846
Restricted cash and cash equivalents	2,352	4,545
Customer accounts receivable (less allowance for credit losses)	68,581	43,852
Accounts receivable - affiliate	13,982	14,605
Other accounts receivable	30,285	27,535
Unbilled revenue	36,759	40,127
Fuel inventory, at average cost	84,534	63,234
Materials and supplies, at average cost	105,090	105,340
Energy risk management assets	6,028	4,337
Accumulated deferred fuel	78,847	28,194
Cash surrender value of company-/trust-owned life insurance policies	16,245	16,184
Prepayments	6,815	7,163
Regulatory assets	18,760	13,305
Other current assets	6,382	830
Total current assets	630,978	394,097
Property, plant, and equipment
Property, plant, and equipment	6,047,103	5,824,378
Accumulated depreciation	(2,242,952)	(2,067,362)
Net property, plant, and equipment	3,804,151	3,757,016
Construction work in progress	128,765	110,613
Total property, plant, and equipment, net	3,932,916	3,867,629
Equity investment in investee	3,822	9,072
Prepayments	1,306	1,496
Operating lease right of use assets	24,642	26,006
Note receivable	13,941	14,506
Regulatory assets	623,820	414,535
Other deferred charges	24,616	38,806
Total assets	5,256,041	4,766,147
Current liabilities
Short-term debt	0	75,000
Long-term debt and finance leases due within one year	736	682
Accounts payable	177,356	106,089
Accounts payable - affiliate	69,356	72,068
Customer deposits	60,186	58,718
Provision for rate refund	5,465	8,630
Taxes payable	42,931	4,778
Interest accrued	21,251	5,357
Energy risk management liabilities	1,330	1,121
Regulatory liabilities	46,003	23,509
Other current liabilities	26,940	24,754
Total current liabilities	451,554	380,706
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	670,036	634,598
Postretirement benefit obligations	237,818	230,825
Regulatory liabilities - deferred taxes, net	99,361	157,056
Asset retirement obligations	21,182	11,364
Operating lease liabilities	21,709	23,295
Other deferred credits	17,385	18,167
Total long-term liabilities and deferred credits	1,067,491	1,075,305
Long-term debt and finance leases, net	1,825,424	1,502,257
Total capitalization	3,736,996	3,310,136
Commitments and contingencies (Note 13)
Member’s equity
Member’s equity	1,911,572	1,807,879
Total liabilities and member’s equity	$ 5,256,041	$ 4,766,147

Condensed Consolidated Balanc_2

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Customer accounts receivable, allowance for credit losses	$ 1,757	$ 2,758
CLECO POWER
Customer accounts receivable, allowance for credit losses	$ 1,757	$ 2,758

Condensed Consolidated Statem_4

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021		Sep. 30, 2020
Operating activities
Net income	$ 219,059		$ 109,793
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	195,619		185,496
Provision for credit losses	3,106		6,134
Unearned compensation expense	7,068		5,113
Allowance for equity funds used during construction	(2,703)		(197)
Gain on risk management assets and liabilities, net	(136,024)		(23,254)
Deferred lease revenue	(6,904)		(6,904)
Deferred income taxes	36,513		39,657
Cash surrender value of company-/trust-owned life insurance	(5,223)		3,586
Changes in assets and liabilities
Accounts receivable	(56,922)		(14,683)
Accounts receivable, affiliate	(1,375)		(39)
Unbilled revenue	3,368		(1,297)
Fuel inventory and materials and supplies	(3,198)		(26,747)
Prepayments	(8,573)		(12,895)
Accounts payable	(11,680)		(30,633)
Accounts payable - affiliate	0		1,469
Customer deposits	8,295		4,688
Provision for merger commitments	(1,881)		738
Postretirement benefit obligations	6,262		4,654
Regulatory assets and liabilities, net	(95,294)		(12,264)
Deferred fuel recoveries	(50,986)		(21,076)
Other deferred accounts	(9,163)		(13,799)
Taxes accrued	26,864		30,132
Interest accrued	23,961		21,063
Energy risk management collateral received	8,900		0
Other operating	(9,295)		6,344
Net cash provided by operating activities	139,794		255,079
Investing activities
Additions to property, plant, and equipment	(209,960)		(215,692)
Allowance for equity funds used during construction	2,703		197
Proceeds from sale of property, plant, and equipment	1,445		259
Return of equity investment in investee	5,250		4,000
Other investing	1,469		562
Net cash used in investing activities	(199,093)		(210,674)
Financing activities
Draws on revolving credit facility	185,000		238,000
Payments on revolving credit facility	(260,000)		0
Issuances of long-term debt	325,000		125,000
Repayment of long-term debt	0		(11,055)
Payment of financing costs	(4,149)		(4,448)
Other financing	(505)		(456)
Net cash provided by financing activities	245,346		347,041
Net increase in cash, cash equivalents, restricted cash, and restricted cash equivalents	186,047		391,446
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	276,312	[1]	534,041
Supplementary cash flow information
Interest paid, net of amount capitalized	70,387		73,714
Income taxes paid (refunded), net	205		(2,777)
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	45,646		89,604
CLECO POWER
Operating activities
Net income	102,407		76,156
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	132,986		129,740
Provision for credit losses	3,106		5,746
Unearned compensation expense	1,746		1,135
Allowance for equity funds used during construction	(2,703)		(197)
Deferred income taxes	(1,737)		5,358
Cash surrender value of company-/trust-owned life insurance	(61)		1,418
Changes in assets and liabilities
Accounts receivable	(38,558)		(29,942)
Accounts receivable, affiliate	4,187		3,751
Unbilled revenue	3,368		(1,297)
Fuel inventory and materials and supplies	(21,326)		(9,511)
Prepayments	210		1,107
Accounts payable	(4,067)		(22,666)
Accounts payable - affiliate	(2,389)		1,015
Customer deposits	8,295		4,688
Provision for merger commitments	(1,381)		(1,574)
Postretirement benefit obligations	4,910		2,581
Regulatory assets and liabilities, net	(96,785)		(13,755)
Deferred fuel recoveries	(50,986)		(21,076)
Other deferred accounts	(6,394)		(14,490)
Taxes accrued	30,789		50,638
Interest accrued	15,893		13,589
Other operating	(6,807)		5,573
Net cash provided by operating activities	74,703		187,987
Investing activities
Additions to property, plant, and equipment	(202,940)		(205,765)
Allowance for equity funds used during construction	2,703		197
Proceeds from sale of property, plant, and equipment	1,445		259
Return of equity investment in investee	5,250		4,000
Other investing	1,469		562
Net cash used in investing activities	(192,073)		(200,747)
Financing activities
Draws on revolving credit facility	185,000		150,000
Payments on revolving credit facility	(260,000)		0
Issuances of long-term debt	325,000		125,000
Repayment of long-term debt	0		(11,055)
Payment of financing costs	(2,846)		(1,619)
Other financing	(505)		(456)
Net cash provided by financing activities	246,649		261,870
Net increase in cash, cash equivalents, restricted cash, and restricted cash equivalents	129,279		249,110
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	158,670	[2]	330,062
Supplementary cash flow information
Interest paid, net of amount capitalized	35,065		34,454
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$ 45,305		$ 88,939
[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 $273,215, current restricted cash and cash equivalents of $2,352, and non-current restricted cash and cash equivalents of $745.
[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 $156,318 and current restricted cash and cash equivalents of $2,352.

Condensed Consolidated Statem_5

Condensed Consolidated Statements of Cash Flows (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Cash and cash equivalents	$ 273,215	$ 84,976
Restricted cash and cash equivalents, current	2,352	4,545
Restricted cash and cash equivalents, noncurrent	745	744
CLECO POWER
Cash and cash equivalents	156,318	24,846
Restricted cash and cash equivalents, current	$ 2,352	$ 4,545

Condensed Consolidated Statem_6

Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited) - USD ($) $ in Thousands	Total	MEMBERSHIP INTEREST	RETAINED EARNINGS	AOCI	CLECO POWER	CLECO POWERMEMBERSHIP INTEREST	CLECO POWERAOCI
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	109,793		109,793		76,156	76,156
Other comprehensive income (loss), net of tax	1,304			1,304	1,409		1,409
Balances, end of period at Sep. 30, 2020	2,754,103	2,454,276	316,036	(16,209)	1,790,957	1,812,133	(21,176)
Balances, beginning of period at Jun. 30, 2020	2,693,358	2,454,276	255,739	(16,657)	1,754,429	1,776,041	(21,612)
Increase (Decrease) in Equity [Roll Forward]
Net income	60,297		60,297		36,092	36,092
Other comprehensive income (loss), net of tax	448			448	436		436
Balances, end of period at Sep. 30, 2020	2,754,103	2,454,276	316,036	(16,209)	1,790,957	1,812,133	(21,176)
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	219,059		219,059		102,407	102,407
Other comprehensive income (loss), net of tax	304			304	1,286		1,286
Balances, end of period at Sep. 30, 2021	2,976,386	2,454,276	547,602	(25,492)	1,911,572	1,935,039	(23,467)
Balances, beginning of period at Jun. 30, 2021	2,856,380	2,454,276	427,692	(25,588)	1,854,598	1,878,478	(23,880)
Increase (Decrease) in Equity [Roll Forward]
Net income	119,910		119,910		56,561	56,561
Other comprehensive income (loss), net of tax	96			96	413		413
Balances, end of period at Sep. 30, 2021	$ 2,976,386	$ 2,454,276	$ 547,602	$ (25,492)	$ 1,911,572	$ 1,935,039	$ (23,467)

Summary of Significant Accounti

Summary of Significant Accounting Policies	9 Months Ended
	Sep. 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. Due to the decrease in the number of COVID-19 cases, effective October 27, 2021, the mandatory, state-wide mask mandate was once again revoked. 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, OSHA, and other governmental and regulatory authorities. 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. On September 9, 2021, the Presidential Administration announced mandatory COVID-19 vaccination plans impacting federal contractors and employees of companies having 100 or more employees. On November 4, 2021, OSHA announced a new emergency temporary standard requiring employers with 100 or more employees to develop, implement, and enforce a mandatory COVID-19 vaccination policy, unless they adopt a policy requiring employees to choose to either be vaccinated or undergo regular COVID-19 testing and wear a face covering at work. Cleco is closely monitoring updates concerning these vaccination mandates and any potential impacts they may have on its businesses and workforce. The impact of these vaccination standards could have an adverse impact on Cleco’s workforce, labor relations, and operations. In March 2020, the LPSC issued an executive order prohibiting the disconnection of utilities for nonpayment. At September 30, 2021, Cleco Power had a regulatory asset of $3.0 million recorded for expenses incurred related to the executive order, as allowed by the LPSC. 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 at this time, due to numerous uncertainties. However, 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 for a fair statement of 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 SEPT. 30, 2021 AT DEC. 31, 2020 Current Cleco Katrina/Rita storm recovery surcharge $ 1,674 $ 2,626 Cleco Power’s charitable contributions 678 1,718 Cleco Power’s rate credit escrow — 201 Total current 2,352 4,545 Non-current Diversified Lands’ mitigation escrow 22 22 Cleco Cajun’s defense fund 723 722 Total non-current 745 744 Total restricted cash and cash equivalents $ 3,097 $ 5,289 Cleco Power (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current Cleco Katrina/Rita storm recovery surcharge $ 1,674 $ 2,626 Charitable contributions 678 1,718 Rate credit escrow — 201 Total restricted cash and cash equivalents $ 2,352 $ 4,545 Prior to the repayment of the storm recovery bonds at their scheduled maturity 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. In April 2021, after payments for all final administrative and winding up activities of Cleco Katrina/Rita were made, Cleco Katrina/Rita transferred its remaining restricted cash to Cleco Power to 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 economic decline during 2020 and 2021, primarily related to the COVID-19 pandemic and weather-related events, the economic outlook at September 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 SEPT. 30, 2021 FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) ACCOUNTS OTHER* TOTAL ACCOUNTS OTHER* TOTAL Balances, beginning of period $ 1,334 $ 1,638 $ 2,972 $ 2,758 $ 1,638 $ 4,396 Current period provision 567 — 567 3,057 — 3,057 Charge-offs (730) — (730) (5,172) — (5,172) Recovery 586 — 586 1,114 — 1,114 Balances, Sept. 30, 2021 $ 1,757 $ 1,638 $ 3,395 $ 1,757 $ 1,638 $ 3,395 * Loan held at Diversified Lands that was fully reserved for at September 30, 2021. FOR THE THREE MONTHS ENDED SEPT. 30, 2020 FOR THE NINE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) ACCOUNTS OTHER* TOTAL ACCOUNTS OTHER* TOTAL Balances, beginning of period $ 3,486 $ 1,638 $ 5,124 $ 3,005 $ 1,250 $ 4,255 CECL adoption — — — 71 — 71 Current period provision 2,041 — 2,041 5,675 388 6,063 Charge-offs — — — (4,091) — (4,091) Recovery 54 — 54 921 — 921 Balances, Sept. 30, 2020 $ 5,581 $ 1,638 $ 7,219 $ 5,581 $ 1,638 $ 7,219 * Loan held at Diversified Lands that was fully reserved for at September 30, 2020. Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, 2021 FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) ACCOUNTS RECEIVABLE Balances, beginning of period $ 1,334 $ 2,758 Current period provision 567 3,057 Charge-offs (730) (5,172) Recovery 586 1,114 Balances, Sept. 30, 2021 $ 1,757 $ 1,757

Recent Authoritative Guidance

Recent Authoritative Guidance	9 Months Ended
	Sep. 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. Certain debt contracts have been 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.

Leases

Leases	9 Months Ended
	Sep. 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 nine months ended September 30, 2021, and 2020, was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Fixed payments $ 10,000 $ 10,000 $ 30,000 $ 30,000 Variable payments 4,938 5,190 15,413 15,950 Amortization of deferred lease liability * 2,301 2,301 6,904 6,904 Total lease income $ 17,239 $ 17,491 $ 52,317 $ 52,854
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 nine months ended September 30, 2021, and 2020, was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Fixed payments $ 10,000 $ 10,000 $ 30,000 $ 30,000 Variable payments 4,938 5,190 15,413 15,950 Amortization of deferred lease liability * 2,301 2,301 6,904 6,904 Total lease income $ 17,239 $ 17,491 $ 52,317 $ 52,854
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 nine months ended September 30, 2021, and 2020, was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Fixed payments $ 10,000 $ 10,000 $ 30,000 $ 30,000 Variable payments 4,938 5,190 15,413 15,950 Amortization of deferred lease liability * 2,301 2,301 6,904 6,904 Total lease income $ 17,239 $ 17,491 $ 52,317 $ 52,854

Revenue Recognition

Revenue Recognition	9 Months Ended
	Sep. 30, 2021
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Note 4 — Revenue Recognition Operating revenue, net for the three and nine months ended September 30, 2021, and 2020, was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) CLECO POWER CLECO CAJUN OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 148,522 $ — $ — $ — $ 148,522 Commercial (1) 82,711 — — — 82,711 Industrial (1) 45,446 — — — 45,446 Other retail (1) 4,479 — — — 4,479 Electric customer credits (764) — — — (764) Total retail revenue 280,394 — — — 280,394 Wholesale, net 74,831 (1) 107,501 (2,420) (2) — 179,912 Transmission, net 17,235 (3) 17,903 — (2,217) 32,921 Other 5,618 — — — 5,618 Affiliate (4) 1,380 — 32,116 (33,496) — Total revenue from contracts with customers 379,458 125,404 29,696 (35,713) 498,845 Revenue unrelated to contracts with customers Other 1,094 (5) 17,254 (6) 1 — 18,349 Total revenue unrelated to contracts with customers 1,094 17,254 1 — 18,349 Operating revenue, net $ 380,552 $ 142,658 $ 29,697 $ (35,713) $ 517,194 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements. (3) Includes $0.1 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 $14.9 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization. FOR THE THREE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) CLECO POWER CLECO CAJUN OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 128,981 $ — $ — $ — $ 128,981 Commercial (1) 68,220 — — — 68,220 Industrial (1) 32,809 — — — 32,809 Other retail (1) 3,614 — — — 3,614 Electric customer credits (16,534) — — — (16,534) Total retail revenue 217,090 — — — 217,090 Wholesale, net 52,216 (1) 99,956 (2,420) (2) — 149,752 Transmission, net 14,656 13,818 — (1,510) 26,964 Other 3,118 — — — 3,118 Affiliate (3) 1,506 — 35,522 (37,028) — Total revenue from contracts with customers 288,586 113,774 33,102 (38,538) 396,924 Revenue unrelated to contracts with customers Other 3,013 (4) 17,513 (5) 1 — 20,527 Total revenue unrelated to contracts with customers 3,013 17,513 1 — 20,527 Operating revenue, net $ 291,599 $ 131,287 $ 33,103 $ (38,538) $ 417,451 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements. (3) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation. (4) Realized gains associated with FTRs. (5) Includes $15.2 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization. FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) CLECO POWER CLECO CAJUN OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 348,918 $ — $ — $ — $ 348,918 Commercial (1) 214,129 — — — 214,129 Industrial (1) 119,497 — — — 119,497 Other retail (1) 11,925 — — — 11,925 Electric customer credits (40,794) — — — (40,794) Total retail revenue 653,675 — — — 653,675 Wholesale, net 182,769 (1) 300,415 (7,260) (2) — 475,924 Transmission, net 44,530 (3) 46,733 (4) — (5,752) 85,511 Other 13,509 — — (1) 13,508 Affiliate (5) 4,259 — 85,392 (89,651) — Total revenue from contracts with customers 898,742 347,148 78,132 (95,404) 1,228,618 Revenue unrelated to contracts with customers Other 9,953 (6) 52,362 (7) 4 — 62,319 Total revenue unrelated to contracts with customers 9,953 52,362 4 — 62,319 Operating revenue, net $ 908,695 $ 399,510 $ 78,136 $ (95,404) $ 1,290,937 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements. (3) Includes $0.4 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 $45.4 million in lease revenue related to the Cottonwood Sale Leaseback and $6.9 million of deferred lease revenue amortization. FOR THE NINE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) CLECO POWER CLECO CAJUN OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 308,525 $ — $ — $ — $ 308,525 Commercial (1) 190,905 — — — 190,905 Industrial (1) 94,227 — — — 94,227 Other retail (1) 10,416 — — — 10,416 Surcharge 2,440 — — — 2,440 Electric customer credits (33,219) — — — (33,219) Total retail revenue 573,294 — — — 573,294 Wholesale, net 140,139 (1) 273,836 (7,260) (2) — 406,715 Transmission, net 38,273 (3) 39,880 (4) — (4,966) 73,187 Other 10,416 — — 1 10,417 Affiliate (5) 3,852 204 93,938 (97,994) — Total revenue from contracts with customers 765,974 313,920 86,678 (102,959) 1,063,613 Revenue unrelated to contracts with customers Other 6,272 (6) 52,895 (7) 2 — 59,169 Total revenue unrelated to contracts with customers 6,272 52,895 2 — 59,169 Operating revenue, net $ 772,246 $ 366,815 $ 86,680 $ (102,959) $ 1,122,782 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements. (3) Includes $0.8 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 $46.0 million in lease revenue related to the Cottonwood Sale Leaseback and $6.9 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 September 30, 2021, Cleco and Cleco Power had $65.7 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.

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	9 Months Ended
	Sep. 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 REMAINING RECOVERY PERIOD (YRS.) (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Regulatory assets Acadia Unit 1 acquisition costs $ 1,939 $ 2,019 18.5 Accumulated deferred fuel (1) 78,847 28,194 Various (2) AFUDC equity gross-up 67,348 69,670 Various (3) Affordability study 13,438 — 10 AMI deferred revenue requirement 2,181 2,591 4 AROs (1)(7) 8,060 5,488 Bayou Vista to Segura deferred revenue requirement (7) 287 — Coughlin transaction costs 853 876 28 COVID-19 executive order (7) 2,953 2,953 Deferred storm restoration costs - Hurricane Delta (7) 17,866 17,051 Deferred storm restoration costs - Hurricane Ida (7) 36,836 — Deferred storm restoration costs - Hurricane Laura (7) 56,815 54,406 Deferred storm restoration costs - Hurricane Zeta (7) 3,496 3,493 Deferred storm restoration costs - Winter Storms Uri & Viola (7) 1,974 — Dolet Hills Power Station closure costs (7) 112,158 48,982 Emergency declarations — 270 — Energy efficiency 1,998 2,820 1.5 Financing costs (1) 6,919 7,184 Various (4) Interest costs 3,521 3,708 Various (3) Lignite Mine closure costs (7) 93,093 — Madison Unit 3 property taxes (7) 6,272 — Non-service cost of postretirement benefits 11,662 9,901 Various (3) Other 13,247 4,229 Various (2) Postretirement costs 149,883 165,437 Various (5) Production operations and maintenance expenses 1,998 4,058 Various (6) Rodemacher Unit 2 deferred costs (7) 5,519 1,333 St. Mary Clean Energy Center 6,524 3,479 4 Training costs 5,968 6,085 38.5 Tree trimming costs 9,771 11,807 3.5 Total regulatory assets 721,426 456,034 Regulatory liabilities AFUDC (7) (6,500) (4,218) Corporate franchise tax, net — (763) — Deferred taxes, net (138,864) (175,584) Various Total regulatory liabilities (145,364) (180,565) Total regulatory assets, net $ 576,062 $ 275,469 (1) Represents regulatory assets for past expenditures that were not earning a return on investment at September 30, 2021, and December 31, 2020, respectively. All other assets are earning a return on investment. (2) For more information related to the remaining recovery period, refer to the following disclosures for each specific regulatory asset or liability. (3) Amortized over the estimated lives of the respective assets. (4) Amortized over the terms of the related debt issuances. (5) Amortized over the average service life of the remaining plan participants. (6) Deferral is recovered over the following three year regulatory period. (7) Currently not in a recovery period. The following table summarizes Cleco’s net regulatory assets and liabilities: Cleco (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Total Cleco Power regulatory assets, net $ 576,062 $ 275,469 2016 Merger adjustments * Fair value of long-term debt 114,001 119,553 Postretirement costs 13,921 15,411 Financing costs 7,334 7,592 Debt issuance costs 5,004 5,254 Total Cleco regulatory assets, net $ 716,322 $ 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 U.S., 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 defer $50.0 million of these costs and recover them over 12 months through Cleco Power’s FAC 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.” Higher lignite and natural gas costs also contributed to the increase in Cleco Power’s accumulated deferred fuel. 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. Bayou Vista To Segura Deferred Revenue Requirement 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 and recover the revenue requirements, including interest at Cleco Power’s weighted average cost of capital, upon the completion of each phase of the Bayou Vista to Segura Transmission project. The northern phase of the project was completed in August 2021. At September 30, 2021, Cleco Power had a regulatory asset of $0.3 million related to deferred revenue associated with the northern phase of the Bayou Vista to Segura Transmission project. The regulatory asset will be amortized over 12 months beginning July 1, 2022. Deferred Storm Restoration Costs — Hurricane Ida On August 29, 2021, Hurricane Ida made landfall in southeast Louisiana as a Category 4 storm, causing power outages for approximately 100,000 of Cleco Power’s electric customers located primarily in southeastern Louisiana. On September 22, 2021, the LPSC approved Cleco Power’s establishment of a regulatory asset to track and defer non-capital expenses associated with the hurricane. For more information about Hurricane Ida, see Note 17 — “Storm Restoration — Hurricane Ida.” 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.” Lignite Mine Closure Cost 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 17, 2021, the LPSC approved the establishment of a regulatory asset for certain lignite costs 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 September 30, 2021, Cleco Power had a regulatory asset of $93.1 million for these mine-related incurred costs. For more information on the Oxbow mine, see Note 13 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Risks and Uncertainties.” 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 income taxes. At September 30, 2021, Cleco Power had a regulatory asset of $6.3 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 capped at $5.7 million. The amount recorded in the regulatory asset at June 30, 2021, began being amortized over 12 months on July 1, 2021. Amounts recorded in the regulatory asset after June 30, 2021, are being amortized over the remaining regulatory period ending June 30, 2022. At September 30, 2021, Cleco Power had a regulatory asset of $4.2 million relating to the Northlake Transmission Agreement. In addition, the LPSC approved recovery of other previously deferred costs associated with Cleco Power’s recently approved retail rate plan, which began being amortized over four years on July 1, 2021. At September 30, 2021, Cleco Power had a regulatory asset of $3.9 million for deferred costs. 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. As approved by the LPSC in Cleco Power’s new retail rate plan, the regulatory asset began being amortized over four years on July 1, 2021. At September 30, 2021, Cleco Power had a regulatory asset of $5.1 million related to the deferred revenue associated with the Coughlin Pipeline project. St. Mary Clean Energy Center Cleco Power had a regulatory asset for revenue requirements related to the St. Mary Clean Energy Center project. As approved by the LPSC in Cleco Power’s new retail rate plan, the regulatory asset began being amortized over four years on July 1, 2021.

Fair Value Accounting and Finan

Fair Value Accounting and Financial Instruments	9 Months Ended
	Sep. 30, 2021
Fair Value Disclosures [Abstract]
Fair Value Accounting and Financial Instruments	Note 6 — Fair Value Accounting and Financial Instruments The amounts reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 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 SEPT. 30, 2021 AT DEC. 31, 2020 (THOUSANDS) CARRYING FAIR VALUE CARRYING FAIR VALUE Long-term debt $ 3,550,179 $ 3,836,960 $ 3,230,500 $ 3,541,349 * The carrying value of long-term debt does not include deferred issuance costs of $14.1 million at Cleco Power AT SEPT. 30, 2021 AT DEC. 31, 2020 (THOUSANDS) CARRYING FAIR VALUE CARRYING FAIR VALUE Long-term debt $ 1,820,177 $ 2,100,029 $ 1,494,947 $ 1,794,799 * The carrying value of long-term debt does not include deferred issuance costs of $8.5 million at 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 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. During the nine months ended September 30, 2021, and the year ended December 31, 2020, Cleco did not experience any transfers between levels within the fair value hierarchy. The following tables disclose for Cleco and Cleco Power the fair value of financial assets and liabilities measured on a recurring basis. These amounts are presented on a gross basis before consideration of amounts netted under master netting agreements and the application of collateral received or paid: Cleco FAIR VALUE MEASUREMENTS AT REPORTING DATE (THOUSANDS) AT SEPT. 30, 2021 QUOTED PRICES SIGNIFICANT SIGNIFICANT AT DEC. 31, 2020 QUOTED PRICES SIGNIFICANT SIGNIFICANT Asset description Institutional money market funds $ 252,807 $ — $ 252,807 $ — $ 86,001 $ — $ 86,001 $ — FTRs 9,338 — — 9,338 4,805 — — 4,805 Natural gas derivatives* 132,892 — 132,892 — 8,599 — 8,599 — Total assets $ 395,037 $ — $ 385,699 $ 9,338 $ 99,405 $ — $ 94,600 $ 4,805 Liability description FTRs $ 1,589 $ — $ — $ 1,589 $ 1,625 $ — $ — $ 1,625 Natural gas derivatives* — — — — 1,612 — 1,612 — Total liabilities $ 1,589 $ — $ — $ 1,589 $ 3,237 $ — $ 1,612 $ 1,625 * Natural gas derivatives include fixed price physical forwards and swap transactions. Cleco Power FAIR VALUE MEASUREMENTS AT REPORTING DATE (THOUSANDS) AT SEPT. 30, 2021 QUOTED PRICES IN ACTIVE MARKETS SIGNIFICANT SIGNIFICANT AT DEC. 31, 2020 QUOTED PRICES SIGNIFICANT SIGNIFICANT Asset description Institutional money market funds $ 135,763 $ — $ 135,763 $ — $ 25,357 $ — $ 25,357 $ — FTRs 6,028 — — 6,028 4,337 — — 4,337 Total assets $ 141,791 $ — $ 135,763 $ 6,028 $ 29,694 $ — $ 25,357 $ 4,337 Liability description FTRs $ 1,330 $ — $ — $ 1,330 $ 1,121 $ — $ — $ 1,121 Total liabilities $ 1,330 $ — $ — $ 1,330 $ 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 SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Beginning balance $ 7,501 $ 8,040 $ 3,180 $ 5,778 Unrealized gains (losses)* 3,955 4 18,861 (736) Purchases 619 443 11,426 10,175 Settlements (4,326) (3,160) (25,718) (9,890) Ending balance $ 7,749 $ 5,327 $ 7,749 $ 5,327 * Cleco Power’s unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet. Cleco Cajun’s unrealized gains (losses) are reported through Purchased power on Cleco’s Condensed Consolidated Income Statement. Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Beginning balance $ 5,990 $ 7,511 $ 3,216 $ 5,725 Unrealized gains* 1,196 426 545 1,355 Purchases 619 443 9,236 8,219 Settlements (3,107) (2,968) (8,299) (9,887) Ending balance $ 4,698 $ 5,412 $ 4,698 $ 5,412 * Unrealized gains are reported through Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheet. 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. 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 September 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 Sept. 30, 2021 $ 9,338 $ 1,589 RTO auction pricing FTR price - per MWh $ (8.18) $ 9.16 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 Sept. 30, 2021 $ 6,028 $ 1,330 RTO auction pricing FTR price - per MWh $ (3.26) $ 9.16 FTRs at Dec. 31, 2020 $ 4,337 $ 1,121 RTO auction pricing FTR price - per MWh $ (3.34) $ 4.36 As a result of the 2016 Merger, fair value adjustments were recorded on Cleco’s Condensed Consolidated Balance Sheet for the valuation of a finite intangible asset relating to the Cleco Power trade name. In August 2021, a wholesale customer that is currently under contract with Cleco Power through March 31, 2024, informed Cleco Power that it was not selected through its RFP process as a provider of load after the first quarter of 2024. Cleco considered this to be a triggering event and determined that the carrying value of the trade name intangible asset may not be recoverable. Therefore, a valuation of the Cleco Power trade name was conducted to test for impairment. A discounted cash flow model utilizing an estimated weighted average cost of capital of 8% was used to determine the fair value of the Cleco Power trade name. As a result, Cleco determined that the fair value of the Cleco Power trade name was less than its carrying value and an impairment of $3.8 million was recognized reducing the carrying value to zero. The fair value measurement of the intangible asset is classified as Level 3 in the fair value hierarchy. For more information on the Cleco Power trade name intangible asset, see Note 15 — “Intangible Assets and Liabilities.” Concentrations of Credit Risk At September 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 September 30, 2021, and December 31, 2020: Cleco (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Cash and cash equivalents $ 249,711 $ 80,712 Current restricted cash and cash equivalents $ 2,352 $ 4,545 Non-current restricted cash and cash equivalents $ 744 $ 744 Cleco Power (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Cash and cash equivalents $ 133,411 $ 20,812 Current restricted cash and cash equivalents $ 2,352 $ 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. 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. Commodity Contracts On Cleco’s Condensed Consolidated Balance Sheets, the fair value of amounts associated with Cleco Cajun’s derivative instruments are offset with related cash collateral balances with the same counterparty. There were no offsetting amounts at December 31, 2020. 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 September 30, 2021, and December 31, 2020: Cleco DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS AT SEPT. 30, 2021 AT DEC. 31, 2020 GROSS AMOUNTS OFFSET ON THE BALANCE SHEET GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1) (THOUSANDS) BALANCE SHEET LINE ITEM GROSS ASSET (LIABILITY) CONTRACT NETTING COLLATERAL NET ASSET (LIABILITY) ON THE BALANCE SHEET COLLATERAL NET AMOUNT NET ASSET (LIABILITY) ON THE BALANCE SHEET (2) Commodity-related contracts FTRs Current Energy risk management assets $ 9,338 $ — $ — $ 9,338 $ — $ 9,338 $ 4,805 Current Energy risk management liabilities (1,589) — — (1,589) — (1,589) (1,625) Natural gas derivatives Current Energy risk management assets 59,648 (1,283) (8,900) 49,465 (41,098) 8,367 8,276 Non-current Energy risk management assets 83,427 — — 83,427 (13,902) 69,525 323 Current Energy risk management liabilities (1,283) 1,283 — — — — (828) Non-current Other deferred credits — — — — — — (784) Commodity-related contracts, net $ 149,541 $ — $ (8,900) $ 140,641 $ (55,000) $ 85,641 $ 10,167 (1) Represents letters of credit by counterparties. (2) There were no offsetting amounts on or off Cleco’s Condensed Consolidated Balance Sheet at December 31, 2020. Cleco Power DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS (THOUSANDS) BALANCE SHEET LINE ITEM AT SEPT. 30, 2021 AT DEC. 31, 2020 Commodity-related contracts FTRs Current Energy risk management assets $ 6,028 $ 4,337 Current Energy risk management liabilities (1,330) (1,121) Commodity-related contracts, net $ 4,698 $ 3,216 At September 30, 2021, cash collateral received from counterparties by Cleco was $8.9 million, all of which was netted against the current portion of Energy risk management assets on Cleco’s Condensed Consolidated Balance Sheet. At December 31, 2020, there was no cash collateral paid or received by Cleco. 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 nine months ended September 30, 2021, and 2020: Cleco AMOUNT OF GAIN(LOSS) ON DERIVATIVES RECOGNIZED IN INCOME FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) INCOME STATEMENT LINE ITEM 2021 2020 2021 2020 Commodity-related contracts FTRs (1) Electric operations $ 1,959 $ 3,013 $ 11,167 $ 6,262 FTRs (1) Purchased power (874) (763) (8,730) (1,053) Natural gas derivatives Fuel used for electric generation 107,687 20,307 165,584 22,515 Total $ 108,772 $ 22,557 $ 168,021 $ 27,724 (1) For the three and nine months ended September 30, 2021, unrealized gains associated with FTRs for Cleco Power of $1.2 million and $0.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the three and nine months ended September 30, 2020, unrealized gains associated with FTRs for Cleco Power of $0.4 million and $1.4 million, respectively, were reported through Accumulated deferred fuel on the balance sheet. Cleco Power AMOUNT OF GAIN(LOSS) ON DERIVATIVES RECOGNIZED IN INCOME FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) INCOME STATEMENT LINE ITEM 2021 2020 2021 2020 Commodity-related contracts FTRs (1) Electric operations $ 1,959 $ 3,013 $ 11,167 $ 6,262 FTRs (1) Purchased power (822) (2,326) (9,236) (4,397) Total $ 1,137 $ 687 $ 1,931 $ 1,865 (1) For the three and nine months ended September 30, 2021, unrealized gains associated with FTRs of $1.2 million and $0.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the three and nine months ended September 30, 2020, unrealized gains associated with FTRs of $0.4 million and $1.4 million, respectively, were reported through Accumulated deferred fuel on the balance sheet. The following table presents the volume of commodity-related derivative contracts outstanding at September 30, 2021, and December 31, 2020, for Cleco and Cleco Power: Cleco TOTAL VOLUME OUTSTANDING (THOUSAND) UNIT OF MEASURE AT SEPT. 30, 2021 AT DEC. 31, 2020 Commodity-related contracts FTRs MWh 22,794 15,269 Natural gas derivatives MMBtus 118,712 73,000 Cleco Power TOTAL VOLUME OUTSTANDING (THOUSAND) UNIT OF MEASURE AT SEPT. 30, 2021 AT DEC. 31, 2020 Commodity-related contracts FTRs MWh 14,596 9,521

Debt

Debt	9 Months Ended
	Sep. 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 incremental interest and commitment fees of 0.125% and 0.05%, respectively. At September 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

Pension Plan and Employee Benef

Pension Plan and Employee Benefits	9 Months Ended
	Sep. 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. Cleco has not made, and does not expect to make, any contributions to the pension plan in 2021. 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 nine months ended September 30, 2021, and 2020 were as follows: PENSION BENEFITS OTHER BENEFITS FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE THREE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Components of periodic benefit costs Service cost $ 2,629 $ 2,455 $ 629 $ 600 Interest cost 4,667 5,204 317 418 Expected return on plan assets (5,700) (6,244) — — Amortizations Prior period service credit — (15) — — Net loss 5,184 4,073 373 362 Net periodic benefit cost 6,780 5,473 1,319 1,380 Special/contractual termination benefits 3,270 — — — Total benefit cost $ 10,050 $ 5,473 $ 1,319 $ 1,380 PENSION BENEFITS OTHER BENEFITS FOR THE NINE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Components of periodic benefit costs Service cost $ 7,887 $ 7,365 $ 1,819 $ 1,615 Interest cost 14,001 15,612 962 1,238 Expected return on plan assets (17,101) (18,731) — — Amortizations Prior period service credit — (45) — — Net loss 15,553 12,222 1,143 1,042 Net periodic benefit cost 20,340 16,423 3,924 3,895 Special/contractual termination benefits 3,270 — — — Total benefit cost $ 23,610 $ 16,423 $ 3,924 $ 3,895 Effective September 30, 2021, the pension plan was amended to offer an enhanced pension benefit to certain employees participating in the plan that elect to retire during a certain retirement window. Those certain employees who elected by September 30, 2021, to receive the enhanced pension benefits will receive a 10% increase in calculated pension benefits. This resulted in a special termination benefit cost for Cleco Power and Support Group of $2.4 million and $0.9 million , respectively, included as an expense of the pension plan. 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 nine months ended September 30, 2021, was $1.8 million and $3.6 million, respectively. The expense of the pension plan related to Cleco’s other subsidiaries for the three and nine months ended September 30, 2020, was $0.9 million and $2.6 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 nine months ended September 30, 2021, was $1.2 million and $3.6 million, respectively. The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2020, was $1.1 million and $3.6 million, respectively. The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at September 30, 2021, and December 31, 2020, were as follows: Cleco (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current $ 4,463 $ 4,463 Non-current $ 51,306 $ 51,868 Cleco Power (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current $ 3,865 $ 3,865 Non-current $ 40,261 $ 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 nine months ended September 30, 2021, and 2020 were as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Components of periodic benefit costs Service cost $ 59 $ 100 $ 174 $ 300 Interest cost 634 733 1,903 2,199 Amortizations Prior period service credit (54) (54) (161) (161) Net loss 307 796 921 2,388 Net periodic benefit cost $ 946 $ 1,575 $ 2,837 $ 4,726 The expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2021, was $0.1 million and $0.4 million, respectively. The expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2020, was $0.2 million and $0.7 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 September 30, 2021, and December 31, 2020, were as follows: Cleco (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current $ 4,703 $ 4,703 Non-current $ 90,880 $ 92,522 Cleco Power (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current $ 711 $ 711 Non-current $ 19,240 $ 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 nine months ended September 30, 2021, and 2020 was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 401(k) Plan expense $ 2,512 $ 2,356 $ 7,391 $ 7,509 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 nine months ended September 30, 2021, and 2020 was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 401(k) Plan expense $ 1,185 $ 996 $ 3,511 $ 3,491 Effective September 30, 2021, the 401(k) plan was amended to offer an enhanced 401(k) benefit to certain employees participating in the plan that elect to retire during a certain retirement window. Those certain employees who elected by September 30, 2021, to receive the enhanced 401(k) benefits will receive a one-time contribution up to 30% of the employee’s 2021 base salary in accordance with IRS contribution limits. This resulted in a one-time benefit cost of $0.2 million included as an expense of the 401(k) plan.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 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 nine months ended September 30, 2021, and 2020 : Cleco FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, 2021 2020 2021 2020 Effective tax rate 20.3 % 29.4 % 12.4 % 26.8 % Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, 2021 2020 2021 2020 Effective tax rate 1.0 % 33.4 % (0.2) % 28.8 % For Cleco, the effective income tax rate for the three and nine months ended September 30, 2021, and 2020, were different than the federal statutory rate primarily due to the flow through of tax benefits, including AFUDC; the amortization of excess ADIT; adjustment to record tax expense at the projected annual effective tax rate; adjustments for tax returns as filed; and state tax expense. For Cleco Power, the effective income tax rate for the three and nine months ended September 30, 2021, and 2020, were different than the federal statutory rate primarily due to the flow through of tax benefits, including AFUDC equity; amortization of excess ADIT; adjustment to record tax expense at the projected annual effective tax rate; adjustments for tax returns as filed; 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 September 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 September 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 2018, 2019, and 2020, the IRS has completed its review of years 2018 through 2020, 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 and 2021 tax years. In this phase, the IRS will not accept any disclosures, conduct any reviews, or provide any assurances. The IRS has accepted Cleco’s application for the Compliance Assurance Process for the 2022 tax year. The state income tax years 2018, 2019, and 2020 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 nine months ended September 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 have 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. These include extensions of time to begin construction on certain solar assets eligible for the Investment Tax Credit (ITC), 100% deductibility of business meals in 2021 and 2022, and an extension of the work opportunity tax credit. The ITC 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. Future Tax Reform Cleco is monitoring the President’s current tax reform proposals, as well as the current proposed infrastructure bill. The proposals have the potential to increase the federal statutory corporate income tax rate from the current rate of 21%. Currently, management is unable to predict the impact of the proposals on the Registrants. Cleco is also monitoring possible updates related to a decreased Louisiana state corporate income tax rate proposal and a Louisiana state sales tax proposal to be voted on in November 2021.

Disclosures about Segments

Disclosures about Segments	9 Months Ended
	Sep. 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 Holdings’ 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 Holdings’ 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 Sept. 30, 2021 (THOUSANDS) CLECO POWER CLECO CAJUN TOTAL SEGMENTS Revenue Electric operations $ 357,084 $ 107,500 $ 464,584 Other operations 22,779 35,158 57,937 Affiliate revenue 1,380 — 1,380 Electric customer credits (691) — (691) Operating revenue, net $ 380,552 $ 142,658 $ 523,210 Net income $ 56,561 $ 86,744 $ 143,305 Add: Depreciation and amortization 43,526 12,623 (1) 56,149 Less: Interest income 936 4 940 Add: Interest charges 18,509 1,117 19,626 Add: Federal and state income tax expense 548 29,888 30,436 EBITDA $ 118,208 $ 130,368 $ 248,576 (1) Includes $3.6 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 $ 464,584 $ (2,420) $ — $ 462,164 Other operations 57,937 1 (2,217) 55,721 Affiliate revenue 1,380 32,116 (33,496) — Electric customer credits (691) — — (691) Operating revenue, net $ 523,210 $ 29,697 $ (35,713) $ 517,194 Depreciation and amortization $ 56,149 $ 8,189 (1) $ — $ 64,338 Interest income $ 940 $ 43 $ (42) $ 941 Interest charges $ 19,626 $ 15,044 $ (41) $ 34,629 Federal and state income tax expense $ 30,436 $ 133 $ — $ 30,569 Net income (loss) $ 143,305 $ (23,396) $ 1 $ 119,910 (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 $ 288,852 $ 99,956 $ 388,808 Other operations 17,775 31,331 49,106 Affiliate revenue 1,506 — 1,506 Electric customer credits (16,534) — (16,534) Operating revenue, net $ 291,599 $ 131,287 $ 422,886 Net income $ 36,092 $ 38,357 $ 74,449 Add: Depreciation and amortization 40,268 11,344 (1) 51,612 Less: Interest income 789 10 799 Add: Interest charges 18,441 (484) 17,957 Add: Federal and state income tax expense 18,076 12,258 30,334 EBITDA $ 112,088 $ 61,465 $ 173,553 (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 $ 388,808 $ (2,420) $ — $ 386,388 Other operations 49,106 1 (1,510) 47,597 Affiliate revenue 1,506 35,522 (37,028) — Electric customer credits (16,534) — — (16,534) Operating revenue, net $ 422,886 $ 33,103 $ (38,538) $ 417,451 Depreciation and amortization $ 51,612 $ 4,497 (1) $ — $ 56,109 Interest income $ 799 $ 121 $ (10) $ 910 Interest charges $ 17,957 $ 16,115 $ (12) $ 34,060 Federal and state income tax expense (benefit) $ 30,334 $ (5,260) $ 1 $ 25,075 Net income (loss) $ 74,449 $ (14,154) $ 2 $ 60,297 (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 Nine Months Ended Sept. 30, 2021 (THOUSANDS) CLECO POWER CLECO CAJUN TOTAL SEGMENTS Revenue Electric operations $ 887,191 $ 300,415 $ 1,187,606 Other operations 57,674 98,851 156,525 Affiliate revenue 4,259 — 4,259 Electric customer credits (40,429) 244 (40,185) Operating revenue, net $ 908,695 $ 399,510 $ 1,308,205 Net income $ 102,407 $ 153,719 $ 256,126 Add: Depreciation and amortization 126,534 36,614 (2) 163,148 Less: Interest income 2,404 10 2,414 Add: Interest charges 55,392 786 56,178 Add: Federal and state income tax (benefit) expense (219) 52,561 52,342 EBITDA $ 281,710 $ 243,670 $ 525,380 Additions to property, plant, and equipment $ 202,940 $ 5,904 $ 208,844 Equity investment in investees (1) $ 3,822 $ — $ 3,822 Goodwill (1) $ 1,490,797 $ — $ 1,490,797 Total segment assets (1) $ 6,746,838 $ 1,212,968 $ 7,959,806 (1) Balances as of September 30, 2021. (2) Includes $10.0 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(6.9) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction. 2021 (THOUSANDS) TOTAL SEGMENTS OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 1,187,606 $ (7,260) $ (1) $ 1,180,345 Other operations 156,525 4 (5,752) 150,777 Affiliate revenue 4,259 85,392 (89,651) — Electric customer credits (40,185) — — (40,185) Operating revenue, net $ 1,308,205 $ 78,136 $ (95,404) $ 1,290,937 Depreciation and amortization $ 163,148 $ 17,052 (2) $ (1) $ 180,199 Interest income $ 2,414 $ 100 $ (98) $ 2,416 Interest charges $ 56,178 $ 45,732 $ (98) $ 101,812 Federal and state income tax expense (benefit) $ 52,342 $ (21,357) $ — $ 30,985 Net income (loss) $ 256,126 $ (37,068) $ 1 $ 219,059 Additions to property, plant, and equipment $ 208,844 $ 1,116 $ — $ 209,960 Equity investment in investees (1) $ 3,822 $ 19,099 $ (19,099) $ 3,822 Goodwill (1) $ 1,490,797 $ — $ — $ 1,490,797 Total segment assets (1) $ 7,959,806 $ 685,410 $ (249,409) $ 8,395,807 (1) Balances as of September 30, 2021. (2) Includes $7.3 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 $ 752,925 $ 273,836 $ 1,026,761 Other operations 49,443 92,928 142,371 Affiliate revenue 3,852 204 4,056 Electric customer credits (33,974) (153) (34,127) Operating revenue, net $ 772,246 $ 366,815 $ 1,139,061 Net income $ 76,156 $ 84,655 $ 160,811 Add: Depreciation and amortization 125,541 33,385 (2) 158,926 Less: Interest income 2,498 269 2,767 Add: Interest charges 55,624 (353) 55,271 Add: Federal and state income tax expense 30,770 27,280 58,050 EBITDA $ 285,593 $ 144,698 $ 430,291 Additions to property, plant, and equipment $ 205,765 $ 7,908 $ 213,673 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 $9.3 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(6.9) million deferred lease revenue amortization as a result of the Cleco Cajun Transaction. 2020 (THOUSANDS) TOTAL SEGMENTS OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 1,026,761 $ (7,260) $ — $ 1,019,501 Other operations 142,371 2 (4,966) 137,407 Affiliate revenue 4,056 93,938 (97,994) — Electric customer credits (34,127) — 1 (34,126) Operating revenue, net $ 1,139,061 $ 86,680 $ (102,959) $ 1,122,782 Depreciation and amortization $ 158,926 $ 13,575 (2) $ 1 $ 172,502 Interest income $ 2,767 $ 276 $ (79) $ 2,964 Interest charges $ 55,271 $ 48,731 $ (79) $ 103,923 Federal and state income tax expense (benefit) $ 58,050 $ (17,821) $ 1 $ 40,230 Net income (loss) $ 160,811 $ (51,019) $ 1 $ 109,793 Additions to property, plant, and equipment $ 213,673 $ 2,019 $ — $ 215,692 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 $7.3 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 SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Net income $ 119,910 $ 60,297 $ 219,059 $ 109,793 Add: Depreciation and amortization 64,338 56,109 180,199 172,502 Less: Interest income 941 910 2,416 2,964 Add: Interest charges 34,629 34,060 101,812 103,923 Add: Federal and state income tax expense 30,569 25,075 30,985 40,230 Add: Other corporate costs and noncash items (1) 71 (1,078) (4,259) 6,807 Total segment EBITDA $ 248,576 $ 173,553 $ 525,380 $ 430,291 (1) Adjustments made for Other and Elimination totals not allocated to total segment EBITDA.

Regulation and Rates

Regulation and Rates	9 Months Ended
	Sep. 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 SEPT. 30, 2021 AT DEC. 31, 2020 Cleco Katrina/Rita storm recovery charges $ 1,610 $ 1,617 FERC audit $ — $ 1,912 FRP $ 1,236 $ 1,786 Site-specific industrial customer $ 611 $ 710 TCJA $ 2,057 $ 2,057 Transmission ROE $ — $ 595 Cleco Katrina/Rita Storm Recovery Charges Prior to the repayment of the Cleco Katrina/Rita 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. In April 2021, after payments for all final administrative and winding up activities of Cleco Katrina/Rita were made, Cleco Katrina/Rita transferred its remaining restricted cash to Cleco Power. As a result, at September 30, 2021, Cleco Power had $1.6 million accrued for amounts to be used to benefit retail customers in a manner and timing as approved by the LPSC. For more information on Cleco Katrina/Rita’s storm recovery, see Note 1 — “Summary of Significant Accounting Policies — Restricted Cash and Cash Equivalents.” FERC Audit As of September 30, 2021, $4.4 million, including accrued interest, was fully refunded to Cleco Power’s wholesale transmission customers as a combination of refund payments related to the FERC audit findings 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.” 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. 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 September 22, 2021, the LPSC approved the 2019 monitoring report indicating no refund was due. 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. In September 2021, Cleco Power refunded $1.2 million for the period of July 1, 2019, through June 30, 2020. At September 30, 2021, Cleco Power had $1.2 million accrued for the period July 1, 2020, through June 30, 2021, which is expected to be refunded to customers in 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 December 1, 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 September 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 September 30, 2021, Cleco Power had $313.9 million accrued for the excess ADIT, of which $39.5 million is reflected in current regulatory liabilities. 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. The complaints covered the period December 2013 through May 2016. As of September 30, 2021, the overcollection due to the change in ROE was fully refunded. For more information on the ROE complaints, see Note 13 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — Transmission ROE.” 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. On September 7, 2021, Cleco Power made a filing with the LPSC giving notice of its intent to consider retiring Teche Unit 3, barring any violations of specific applicable reliability standards. Assuming no violations are found, Teche Unit 3 could be retired in 2022. At September 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.

Variable Interest Entities

Variable Interest Entities	9 Months Ended
	Sep. 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 September 30, 2021, consisted of its equity investment of $3.8 million . During the nine months ended September 30, 2021, Cleco Power had a return of equity investment from Oxbow of $5.3 million. The following table presents the components of Cleco Power’s equity investment in Oxbow: INCEPTION TO DATE (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Purchase price $ 12,873 $ 12,873 Cash contributions 6,399 6,399 Distributions (15,450) (10,200) Total equity investment in investee $ 3,822 $ 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 SEPT. 30, 2021 AT DEC. 31, 2020 Oxbow’s net assets/liabilities $ 7,645 $ 18,145 Cleco Power’s 50% equity $ 3,822 $ 9,072 Cleco Power’s maximum exposure to loss $ 3,822 $ 9,072 The following table contains summarized financial information for Oxbow: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Operating revenue $ 1,486 $ 2,275 $ 5,113 $ 33,266 Operating expenses 1,486 2,275 5,113 33,266 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. In June 2020, management decided to retire the Dolet Hills Power Station. On October 6, 2020, Cleco Power and SWEPCO made a joint filing with the LPSC seeking authorization to close the Oxbow mine. As of September 30, 2021, Cleco Power estimates $1.8 million of its proportionate share of costs will be billed by Oxbow prior to the closure of the Dolet Hills Power Station. 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.

Litigation, Other Commitments a

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	9 Months Ended
	Sep. 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. On October 18, 2021, the District Court issued an order consistent with a joint motion by the parties to dismiss all claims against the former independent directors leaving two former executives as the only remaining defendants. 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 12 th 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 16 th 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 16 th 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 16 th 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 with the May 2021 bills. 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. Cleco Power has responded to its first set of data requests. 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. On October 20, 2021, the LPSC approved the EAC audit for the period January 2018 to December 2019 with no findings. The total amount of environmental expense that was included in the audit was $26.2 million. 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 Presidential Administration issued an executive order directing 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 to suspend, revise, or rescind the rule. The EPA has not issued a proposed rule, and management is unable to determine when a proposed rule will be issued. 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 fourth quarter of 2021. As of June 30, 2021, the 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 In November 2013 and February 2015, customers filed complaints 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 covered the period December 2013 through May 2016 and sought to reduce the 12.38% ROE used in MISO’s transmission rates to a proposed 6.68%. 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 September 30, 2021, the overcollection due to the change in the ROE was fully refunded. 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 remediation costs, as defined in the policy of insurance, incurred to install selective non-catalytic reduction equipment on Big Cajun II, Unit 3. This installation served a dual purpose of being a prudent utility practice for compliance with environmental laws and aiding in the settlement of a lawsuit, which was brought by the EPA and the Louisiana Department of Environmental Quality against Louisiana Generating, related to Big Cajun II, Units 1 and 2. Entergy Gulf States, as co-owner of Big Cajun II, Unit 3, expected to be allocated a portion of the insurance settlement proceeds. Litigation between Entergy Gulf States and Louisiana Generating ensued to determine Entergy Gulf States’ allocated amount of insurance proceeds, among other claims pursuant to the Joint Ownership Participation and Operating Agreement between Louisiana Generating and Entergy Gulf States. In August 2021, Louisiana Generating and Entergy Gulf States entered an agreement to settle all claims asserted in this litigation. Upon payment of the settlement amount in January 2022, the lawsuit will be dismissed. NRG Energy will indemnify Cleco for losses associated with this litigation matter. 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 September 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 September 30, 2021, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters are $4.1 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 September 30, 2021, Cleco Power does not expect any payments to be made under this guarantee. 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 17, 2021, the LPSC approved the establishment of a regulatory asset for the deferral of certain accelerated mine costs in fuel and related ratemaking treatment. For more information on the Dolet Hills regulatory asset, see Note 5 — “Regulatory Assets and Liabilities — Lignite Mine Closure Cost.” 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 has 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. In April 2015, the EPA published a final rule in the Federal Register for regulating the disposal and management of CCRs from coal-fired power plants (CCR Rule). The rule established extensive requirements for existing and new CCR landfills and surface impoundments and all lateral expansions consisting of location restrictions, design and operating criteria, groundwater monitoring and corrective action, closure requirements and post closure care, and recordkeeping, notification, and internet posting requirements. In August 2018, the D.C. Court of Appeals vacated several requirements in the CCR regulation, which included eliminating the previous acceptability of compacted clay material as a liner for impoundments. As a result, on December 2, 2019, the EPA published a proposed rule that would set deadlines for costly modifications including retrofitting of clay-lined impoundments with compliant liners or closure of the impoundments. The rule was finalized and published in the Federal Register on August 28, 2020. In November 2020, Cleco submitted demonstrations to the EPA specifying its intended course of action for Rodemacher Unit 2, Dolet Hills Power Station, and Big Cajun II in order to comply with the final rule. During 2021, additional information was submitted to the LDEQ to revise and update Cleco Power’s compliance strategy. Cleco Power and Cleco Cajun have also engaged independent engineering specialists to conduct studies on the efforts and costs expected to be incurred in order to comply with the final CCR rule. During the third quarter of 2021, management received additional information in connection with Cleco Power’s and Cleco Cajun’s compliance strategies resulting in a revision to the estimated cash flows expected to be required to settle the respective AROs. Therefore, Cleco Power and Cleco Cajun recorded an increase of $13.1 million and $35.5 million, respectively, in their ARO balances. The following tables summarize the net changes in the ARO for Cleco and Cleco Power: (THOUSANDS) CLECO CAJUN CLECO POWER CLECO Balance, Dec. 31, 2020 $ 16,658 $ 11,364 $ 28,022 Liabilities settled (1,316) $ — (1,316) Accretion 466 $ 249 715 Revisions and adjustments 35,540 $ 13,101 48,641 Balance, Sept. 30, 2021 $ 51,348 $ 24,714 $ 76,062 As part of the Cleco Cajun Transaction, NRG agreed to indemnify Cleco for environmental costs up to $25.0 million associated with the CCR rule. At September 30, 2021, Cleco Cajun recognized indemnification assets totaling $22.1 million. The current portion of the indemnification asset of $1.1 million is reflected in Other current assets and the non-current portion of $21.0 million is reflected in Other deferred charges on Cleco’s Condensed Consolidated Balance Sheet. The indemnification asset is expected to be collected as closure costs are incurred. 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. Power purchases in the MISO market are made at prevailing market pric

Affiliate Transactions

Affiliate Transactions	9 Months Ended
	Sep. 30, 2021
Related Party Transactions [Abstract]
Affiliate Transactions	Note 14 — Affiliate Transactions At September 30, 2021, and December 31, 2020, Cleco Holdings had an affiliate receivable of $3.0 million and $1.7 million, respectively, from Cleco Group primarily for franchise taxes. At both September 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. Cleco Power has balances that are payable to or due from its affiliates. The following table is a summary of those balances: AT SEPT. 30, 2021 AT DEC. 31, 2020 (THOUSANDS) ACCOUNTS ACCOUNTS ACCOUNTS ACCOUNTS Cleco Holdings $ 10,712 $ 57,825 $ 10,353 $ 57,713 Support Group 2,388 11,514 3,248 14,355 Cleco Cajun 882 17 1,004 — Total $ 13,982 $ 69,356 $ 14,605 $ 72,068 Of the affiliate payable balances at September 30, 2021, and December 31, 2020, Cleco Power had $57.6 million payable to Cleco Holdings for the settlement of income taxes. 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 nine months ended September 30, 2021, Cleco Power recorded $0.7 million and $2.7 million, respectively, of its proportionate share of incurred costs. During the three and nine months ended September 30, 2020, Cleco Power recorded $1.1 million and $16.6 million, respectively, of its proportionate share of incurred costs. At September 30, 2021, and December 31, 2020, Cleco Power had $0.2 million and $0.3 million, respectively, payable to Oxbow. For more information on Cleco Power’s variable interest in Oxbow, see Note 12 — “Variable Interest Entities.”

Intangible Assets and Liabiliti

Intangible Assets and Liabilities	9 Months Ended
	Sep. 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 included $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 finite intangible assets relating to the Cleco Power trade name and long-term wholesale power supply agreements. At the end of their lives, these power supply agreement intangible assets will have no residual value. 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. During the third quarter of 2021, Cleco determined that the fair value of the Cleco Power trade name was less than its carrying value and an impairment of $3.8 million was recognized reducing the carrying value to zero. The impairment resulted in an increase in amortization expense and was reflected in Depreciation and amortization on Cleco’s Condensed Consolidated Statements of Income at September 30, 2021. For more information on the the trade name intangible asset impairment, see Note 6 — “Fair Value Accounting and Financial Instruments.” 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 6 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 SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Intangible assets Cleco Katrina/Rita right to bill and collect storm recovery charges $ — $ — $ — $ 517 Trade name $ 3,770 $ 64 $ 3,897 $ 191 Power supply agreements $ 6,400 $ 6,400 $ 19,200 $ 19,200 Intangible liabilities LTSA $ 871 $ 871 $ 2,613 $ 2,613 Power supply agreements $ 389 $ 882 $ 1,989 $ 2,646 Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS (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 SEPT. 30, 2021 AT DEC. 31, 2020 Intangible assets Trade name $ — $ 5,100 Power supply agreements 184,004 184,004 Total intangible assets carrying amount 184,004 189,104 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 145,704 150,804 Accumulated amortization (77,326) (63,932) Net intangible assets subject to amortization $ 68,378 $ 86,872 Goodwill On April 13, 2016, in connection with the completion of the 2016 Merger, Cleco recognized goodwill of $1.49 billion. Management assigned the recognized goodwill to the Cleco Power reporting unit. Goodwill is required to be tested for impairment at the reporting unit level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. Application of the goodwill impairment test requires significant judgments, including the identification of reporting units, assignments of assets and liabilities to reporting units, assignment of goodwill to reporting units, and the determination of the fair value of the reporting units. Cleco conducted its 2021 annual impairment test using an August 1, 2021, measurement date. The fair value of the Cleco Power reporting unit was estimated using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	9 Months Ended
	Sep. 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 FOR THE NINE (THOUSANDS) POSTRETIREMENT BENEFIT NET LOSS Balances, beginning of period $ (25,588) $ (25,796) Amounts reclassified from AOCI Amortization of postretirement benefit net loss 96 304 Balances, Sept. 30, 2021 $ (25,492) $ (25,492) FOR THE THREE MONTHS ENDED FOR THE NINE MONTHS ENDED (THOUSANDS) POSTRETIREMENT BENEFIT NET LOSS Balances, beginning of period $ (16,657) $ (17,513) Amounts reclassified from AOCI Amortization of postretirement benefit net loss 448 1,304 Balances, Sept. 30, 2020 $ (16,209) $ (16,209) Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, 2021 FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (18,394) $ (5,486) $ (23,880) $ (19,139) $ (5,614) $ (24,753) Amounts reclassified from AOCI Amortization of postretirement benefit net loss 350 — 350 1,095 — 1,095 Reclassification of net loss to interest charges — 63 63 — 191 191 Balances, Sept. 30, 2021 $ (18,044) $ (5,423) $ (23,467) $ (18,044) $ (5,423) $ (23,467) FOR THE THREE MONTHS ENDED SEPT. 30, 2020 FOR THE NINE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (15,872) $ (5,740) $ (21,612) $ (16,717) $ (5,868) $ (22,585) Amounts reclassified from AOCI Amortization of postretirement benefit net loss 373 — 373 1,218 — 1,218 Reclassification of net loss to interest charges — 63 63 — 191 191 Balances, Sept. 30, 2020 $ (15,499) $ (5,677) $ (21,176) $ (15,499) $ (5,677) $ (21,176)

Storm Restoration

Storm Restoration	9 Months Ended
	Sep. 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 $242.6 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 $152.2 million, of the total restoration costs recorded at September 30, 2021. At September 30, 2021, Cleco Power had regulatory assets for non-capital expenses related to Hurricanes Laura, Delta, and Zeta, as allowed by the LPSC, totaling $78.2 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, which is expected in the first quarter of 2022. Cleco Power began collecting this amount through rates on June 1, 2021. 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 U.S., primarily due to prolonged freezing temperatures. Cleco Power’s 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 September 30, 2021. At September 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 with the May 2021 bills. 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. Cleco Power has responded to its first set of data requests. Management is unable to determine the outcome or timing of the audit. 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. Hurricane Ida On August 29, 2021, Hurricane Ida made landfall in southeast Louisiana as a Category 4 storm, causing power outages for approximately 100,000 of Cleco Power’s electric customers located primarily in southeastern Louisiana. By September 11, 2021, power was restored to 100% of customers who could receive power. Cleco Power’s current estimate of total storm restoration costs related to Hurricane Ida is between $85.0 million and $95.0 million. The damage to equipment from the hurricane required replacement, as well as repair of existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 56%, or approximately $49.1 million, of the total restoration costs recorded at September 30, 2021. At September 30, 2021, Cleco Power had a regulatory asset for non-capital expenses related to Hurricane Ida, as allowed by the LPSC, totaling $36.8 million. On September 28, 2021, Cleco Power made a supplemental filing to its application for storm restoration costs securitization to recover costs related to Hurricane Ida. Storm Securitization 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, and Winter Storms Uri and Viola, totaling $342.0 million, including the establishment of a newly funded $100.0 million storm reserve to cover future storm costs. On September 28, 2021, Cleco Power filed supplemental testimony with the LPSC relating to storm securitization requesting an additional $100.0 million for a separate storm reserve to cover costs associated with Hurricane Ida. Cleco Power continues to respond to several sets of data requests received from the LPSC related to the securitization filing. 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 funding from the U.S. government ultimately will be approved.

Summary of Significant Accoun_2

Summary of Significant Accounting Policies (Policies)	9 Months Ended
	Sep. 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. Due to the decrease in the number of COVID-19 cases, effective October 27, 2021, the mandatory, state-wide mask mandate was once again revoked. 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, OSHA, and other governmental and regulatory authorities. 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. On September 9, 2021, the Presidential Administration announced mandatory COVID-19 vaccination plans impacting federal contractors and employees of companies having 100 or more employees. On November 4, 2021, OSHA announced a new emergency temporary standard requiring employers with 100 or more employees to develop, implement, and enforce a mandatory COVID-19 vaccination policy, unless they adopt a policy requiring employees to choose to either be vaccinated or undergo regular COVID-19 testing and wear a face covering at work. Cleco is closely monitoring updates concerning these vaccination mandates and any potential impacts they may have on its businesses and workforce. The impact of these vaccination standards could have an adverse impact on Cleco’s workforce, labor relations, and operations. In March 2020, the LPSC issued an executive order prohibiting the disconnection of utilities for nonpayment. At September 30, 2021, Cleco Power had a regulatory asset of $3.0 million recorded for expenses incurred related to the executive order, as allowed by the LPSC. 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 at this time, due to numerous uncertainties. However, 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 for a fair statement of 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.
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 at their scheduled maturity 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 economic decline during 2020 and 2021, primarily related to the COVID-19 pandemic and weather-related events, the economic outlook at September 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. Certain debt contracts have been 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
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. Cleco has not made, and does not expect to make, any contributions to the pension plan in 2021. 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. 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
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.

Summary of Significant Accoun_3

Summary of Significant Accounting Policies (Tables)	9 Months Ended
	Sep. 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 SEPT. 30, 2021 AT DEC. 31, 2020 Current Cleco Katrina/Rita storm recovery surcharge $ 1,674 $ 2,626 Cleco Power’s charitable contributions 678 1,718 Cleco Power’s rate credit escrow — 201 Total current 2,352 4,545 Non-current Diversified Lands’ mitigation escrow 22 22 Cleco Cajun’s defense fund 723 722 Total non-current 745 744 Total restricted cash and cash equivalents $ 3,097 $ 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 SEPT. 30, 2021 FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) ACCOUNTS OTHER* TOTAL ACCOUNTS OTHER* TOTAL Balances, beginning of period $ 1,334 $ 1,638 $ 2,972 $ 2,758 $ 1,638 $ 4,396 Current period provision 567 — 567 3,057 — 3,057 Charge-offs (730) — (730) (5,172) — (5,172) Recovery 586 — 586 1,114 — 1,114 Balances, Sept. 30, 2021 $ 1,757 $ 1,638 $ 3,395 $ 1,757 $ 1,638 $ 3,395 * Loan held at Diversified Lands that was fully reserved for at September 30, 2021. FOR THE THREE MONTHS ENDED SEPT. 30, 2020 FOR THE NINE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) ACCOUNTS OTHER* TOTAL ACCOUNTS OTHER* TOTAL Balances, beginning of period $ 3,486 $ 1,638 $ 5,124 $ 3,005 $ 1,250 $ 4,255 CECL adoption — — — 71 — 71 Current period provision 2,041 — 2,041 5,675 388 6,063 Charge-offs — — — (4,091) — (4,091) Recovery 54 — 54 921 — 921 Balances, Sept. 30, 2020 $ 5,581 $ 1,638 $ 7,219 $ 5,581 $ 1,638 $ 7,219 * Loan held at Diversified Lands that was fully reserved for at September 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 SEPT. 30, 2021 FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) ACCOUNTS OTHER* TOTAL ACCOUNTS OTHER* TOTAL Balances, beginning of period $ 1,334 $ 1,638 $ 2,972 $ 2,758 $ 1,638 $ 4,396 Current period provision 567 — 567 3,057 — 3,057 Charge-offs (730) — (730) (5,172) — (5,172) Recovery 586 — 586 1,114 — 1,114 Balances, Sept. 30, 2021 $ 1,757 $ 1,638 $ 3,395 $ 1,757 $ 1,638 $ 3,395 * Loan held at Diversified Lands that was fully reserved for at September 30, 2021. FOR THE THREE MONTHS ENDED SEPT. 30, 2020 FOR THE NINE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) ACCOUNTS OTHER* TOTAL ACCOUNTS OTHER* TOTAL Balances, beginning of period $ 3,486 $ 1,638 $ 5,124 $ 3,005 $ 1,250 $ 4,255 CECL adoption — — — 71 — 71 Current period provision 2,041 — 2,041 5,675 388 6,063 Charge-offs — — — (4,091) — (4,091) Recovery 54 — 54 921 — 921 Balances, Sept. 30, 2020 $ 5,581 $ 1,638 $ 7,219 $ 5,581 $ 1,638 $ 7,219 * Loan held at Diversified Lands that was fully reserved for at September 30, 2020.
CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Restricted Cash and Cash Equivalents	Cleco Power (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current Cleco Katrina/Rita storm recovery surcharge $ 1,674 $ 2,626 Charitable contributions 678 1,718 Rate credit escrow — 201 Total restricted cash and cash equivalents $ 2,352 $ 4,545
Changes in Allowance for Credit Losses, Accounts Receivable	Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, 2021 FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) ACCOUNTS RECEIVABLE Balances, beginning of period $ 1,334 $ 2,758 Current period provision 567 3,057 Charge-offs (730) (5,172) Recovery 586 1,114 Balances, Sept. 30, 2021 $ 1,757 $ 1,757 FOR THE THREE MONTHS ENDED SEPT. 30, 2020 FOR THE NINE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) ACCOUNTS RECEIVABLE Balances, beginning of period $ 3,486 $ 3,005 CECL adoption — 71 Current period provision 2,041 5,675 Charge-offs — (4,091) Recovery 54 921 Balances, Sept. 30, 2020 $ 5,581 $ 5,581

Leases (Tables)

Leases (Tables)	9 Months Ended
	Sep. 30, 2021
Leases [Abstract]
Lease Income Under Cottonwood Sale Leaseback	Cleco Cajun’s lease income under the Cottonwood Sale Leaseback for the three and nine months ended September 30, 2021, and 2020, was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Fixed payments $ 10,000 $ 10,000 $ 30,000 $ 30,000 Variable payments 4,938 5,190 15,413 15,950 Amortization of deferred lease liability * 2,301 2,301 6,904 6,904 Total lease income $ 17,239 $ 17,491 $ 52,317 $ 52,854

Revenue Recognition (Tables)

Revenue Recognition (Tables)	9 Months Ended
	Sep. 30, 2021
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	Operating revenue, net for the three and nine months ended September 30, 2021, and 2020, was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) CLECO POWER CLECO CAJUN OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 148,522 $ — $ — $ — $ 148,522 Commercial (1) 82,711 — — — 82,711 Industrial (1) 45,446 — — — 45,446 Other retail (1) 4,479 — — — 4,479 Electric customer credits (764) — — — (764) Total retail revenue 280,394 — — — 280,394 Wholesale, net 74,831 (1) 107,501 (2,420) (2) — 179,912 Transmission, net 17,235 (3) 17,903 — (2,217) 32,921 Other 5,618 — — — 5,618 Affiliate (4) 1,380 — 32,116 (33,496) — Total revenue from contracts with customers 379,458 125,404 29,696 (35,713) 498,845 Revenue unrelated to contracts with customers Other 1,094 (5) 17,254 (6) 1 — 18,349 Total revenue unrelated to contracts with customers 1,094 17,254 1 — 18,349 Operating revenue, net $ 380,552 $ 142,658 $ 29,697 $ (35,713) $ 517,194 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements. (3) Includes $0.1 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 $14.9 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization. FOR THE THREE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) CLECO POWER CLECO CAJUN OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 128,981 $ — $ — $ — $ 128,981 Commercial (1) 68,220 — — — 68,220 Industrial (1) 32,809 — — — 32,809 Other retail (1) 3,614 — — — 3,614 Electric customer credits (16,534) — — — (16,534) Total retail revenue 217,090 — — — 217,090 Wholesale, net 52,216 (1) 99,956 (2,420) (2) — 149,752 Transmission, net 14,656 13,818 — (1,510) 26,964 Other 3,118 — — — 3,118 Affiliate (3) 1,506 — 35,522 (37,028) — Total revenue from contracts with customers 288,586 113,774 33,102 (38,538) 396,924 Revenue unrelated to contracts with customers Other 3,013 (4) 17,513 (5) 1 — 20,527 Total revenue unrelated to contracts with customers 3,013 17,513 1 — 20,527 Operating revenue, net $ 291,599 $ 131,287 $ 33,103 $ (38,538) $ 417,451 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements. (3) Includes interdepartmental rents and support services. This revenue is eliminated upon consolidation. (4) Realized gains associated with FTRs. (5) Includes $15.2 million in lease revenue related to the Cottonwood Sale Leaseback and $2.3 million of deferred lease revenue amortization. FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) CLECO POWER CLECO CAJUN OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 348,918 $ — $ — $ — $ 348,918 Commercial (1) 214,129 — — — 214,129 Industrial (1) 119,497 — — — 119,497 Other retail (1) 11,925 — — — 11,925 Electric customer credits (40,794) — — — (40,794) Total retail revenue 653,675 — — — 653,675 Wholesale, net 182,769 (1) 300,415 (7,260) (2) — 475,924 Transmission, net 44,530 (3) 46,733 (4) — (5,752) 85,511 Other 13,509 — — (1) 13,508 Affiliate (5) 4,259 — 85,392 (89,651) — Total revenue from contracts with customers 898,742 347,148 78,132 (95,404) 1,228,618 Revenue unrelated to contracts with customers Other 9,953 (6) 52,362 (7) 4 — 62,319 Total revenue unrelated to contracts with customers 9,953 52,362 4 — 62,319 Operating revenue, net $ 908,695 $ 399,510 $ 78,136 $ (95,404) $ 1,290,937 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements. (3) Includes $0.4 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 $45.4 million in lease revenue related to the Cottonwood Sale Leaseback and $6.9 million of deferred lease revenue amortization. FOR THE NINE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) CLECO POWER CLECO CAJUN OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 308,525 $ — $ — $ — $ 308,525 Commercial (1) 190,905 — — — 190,905 Industrial (1) 94,227 — — — 94,227 Other retail (1) 10,416 — — — 10,416 Surcharge 2,440 — — — 2,440 Electric customer credits (33,219) — — — (33,219) Total retail revenue 573,294 — — — 573,294 Wholesale, net 140,139 (1) 273,836 (7,260) (2) — 406,715 Transmission, net 38,273 (3) 39,880 (4) — (4,966) 73,187 Other 10,416 — — 1 10,417 Affiliate (5) 3,852 204 93,938 (97,994) — Total revenue from contracts with customers 765,974 313,920 86,678 (102,959) 1,063,613 Revenue unrelated to contracts with customers Other 6,272 (6) 52,895 (7) 2 — 59,169 Total revenue unrelated to contracts with customers 6,272 52,895 2 — 59,169 Operating revenue, net $ 772,246 $ 366,815 $ 86,680 $ (102,959) $ 1,122,782 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to Cleco Power’s wholesale power supply agreements. (3) Includes $0.8 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 $46.0 million in lease revenue related to the Cottonwood Sale Leaseback and $6.9 million of deferred lease revenue amortization.

Regulatory Assets and Liabili_2

Regulatory Assets and Liabilities (Tables)	9 Months Ended
	Sep. 30, 2021
Regulatory Assets [Line Items]
Schedule of Regulatory Assets	The following table summarizes Cleco’s net regulatory assets and liabilities: Cleco (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Total Cleco Power regulatory assets, net $ 576,062 $ 275,469 2016 Merger adjustments * Fair value of long-term debt 114,001 119,553 Postretirement costs 13,921 15,411 Financing costs 7,334 7,592 Debt issuance costs 5,004 5,254 Total Cleco regulatory assets, net $ 716,322 $ 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 REMAINING RECOVERY PERIOD (YRS.) (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Regulatory assets Acadia Unit 1 acquisition costs $ 1,939 $ 2,019 18.5 Accumulated deferred fuel (1) 78,847 28,194 Various (2) AFUDC equity gross-up 67,348 69,670 Various (3) Affordability study 13,438 — 10 AMI deferred revenue requirement 2,181 2,591 4 AROs (1)(7) 8,060 5,488 Bayou Vista to Segura deferred revenue requirement (7) 287 — Coughlin transaction costs 853 876 28 COVID-19 executive order (7) 2,953 2,953 Deferred storm restoration costs - Hurricane Delta (7) 17,866 17,051 Deferred storm restoration costs - Hurricane Ida (7) 36,836 — Deferred storm restoration costs - Hurricane Laura (7) 56,815 54,406 Deferred storm restoration costs - Hurricane Zeta (7) 3,496 3,493 Deferred storm restoration costs - Winter Storms Uri & Viola (7) 1,974 — Dolet Hills Power Station closure costs (7) 112,158 48,982 Emergency declarations — 270 — Energy efficiency 1,998 2,820 1.5 Financing costs (1) 6,919 7,184 Various (4) Interest costs 3,521 3,708 Various (3) Lignite Mine closure costs (7) 93,093 — Madison Unit 3 property taxes (7) 6,272 — Non-service cost of postretirement benefits 11,662 9,901 Various (3) Other 13,247 4,229 Various (2) Postretirement costs 149,883 165,437 Various (5) Production operations and maintenance expenses 1,998 4,058 Various (6) Rodemacher Unit 2 deferred costs (7) 5,519 1,333 St. Mary Clean Energy Center 6,524 3,479 4 Training costs 5,968 6,085 38.5 Tree trimming costs 9,771 11,807 3.5 Total regulatory assets 721,426 456,034 Regulatory liabilities AFUDC (7) (6,500) (4,218) Corporate franchise tax, net — (763) — Deferred taxes, net (138,864) (175,584) Various Total regulatory liabilities (145,364) (180,565) Total regulatory assets, net $ 576,062 $ 275,469 (1) Represents regulatory assets for past expenditures that were not earning a return on investment at September 30, 2021, and December 31, 2020, respectively. All other assets are earning a return on investment. (2) For more information related to the remaining recovery period, refer to the following disclosures for each specific regulatory asset or liability. (3) Amortized over the estimated lives of the respective assets. (4) Amortized over the terms of the related debt issuances. (5) Amortized over the average service life of the remaining plan participants. (6) Deferral is recovered over the following three year regulatory period. (7) Currently not in a recovery period.
Schedule of Regulatory Liabilities	The following table summarizes Cleco Power’s regulatory assets and liabilities: Cleco Power REMAINING RECOVERY PERIOD (YRS.) (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Regulatory assets Acadia Unit 1 acquisition costs $ 1,939 $ 2,019 18.5 Accumulated deferred fuel (1) 78,847 28,194 Various (2) AFUDC equity gross-up 67,348 69,670 Various (3) Affordability study 13,438 — 10 AMI deferred revenue requirement 2,181 2,591 4 AROs (1)(7) 8,060 5,488 Bayou Vista to Segura deferred revenue requirement (7) 287 — Coughlin transaction costs 853 876 28 COVID-19 executive order (7) 2,953 2,953 Deferred storm restoration costs - Hurricane Delta (7) 17,866 17,051 Deferred storm restoration costs - Hurricane Ida (7) 36,836 — Deferred storm restoration costs - Hurricane Laura (7) 56,815 54,406 Deferred storm restoration costs - Hurricane Zeta (7) 3,496 3,493 Deferred storm restoration costs - Winter Storms Uri & Viola (7) 1,974 — Dolet Hills Power Station closure costs (7) 112,158 48,982 Emergency declarations — 270 — Energy efficiency 1,998 2,820 1.5 Financing costs (1) 6,919 7,184 Various (4) Interest costs 3,521 3,708 Various (3) Lignite Mine closure costs (7) 93,093 — Madison Unit 3 property taxes (7) 6,272 — Non-service cost of postretirement benefits 11,662 9,901 Various (3) Other 13,247 4,229 Various (2) Postretirement costs 149,883 165,437 Various (5) Production operations and maintenance expenses 1,998 4,058 Various (6) Rodemacher Unit 2 deferred costs (7) 5,519 1,333 St. Mary Clean Energy Center 6,524 3,479 4 Training costs 5,968 6,085 38.5 Tree trimming costs 9,771 11,807 3.5 Total regulatory assets 721,426 456,034 Regulatory liabilities AFUDC (7) (6,500) (4,218) Corporate franchise tax, net — (763) — Deferred taxes, net (138,864) (175,584) Various Total regulatory liabilities (145,364) (180,565) Total regulatory assets, net $ 576,062 $ 275,469 (1) Represents regulatory assets for past expenditures that were not earning a return on investment at September 30, 2021, and December 31, 2020, respectively. All other assets are earning a return on investment. (2) For more information related to the remaining recovery period, refer to the following disclosures for each specific regulatory asset or liability. (3) Amortized over the estimated lives of the respective assets. (4) Amortized over the terms of the related debt issuances. (5) Amortized over the average service life of the remaining plan participants. (6) Deferral is recovered over the following three year regulatory period. (7) Currently not in a recovery period.

Fair Value Accounting and Fin_2

Fair Value Accounting and Financial Instruments (Tables)	9 Months Ended
	Sep. 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 SEPT. 30, 2021 AT DEC. 31, 2020 (THOUSANDS) CARRYING FAIR VALUE CARRYING FAIR VALUE Long-term debt $ 3,550,179 $ 3,836,960 $ 3,230,500 $ 3,541,349 * The carrying value of long-term debt does not include deferred issuance costs of $14.1 million at
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. These amounts are presented on a gross basis before consideration of amounts netted under master netting agreements and the application of collateral received or paid: Cleco FAIR VALUE MEASUREMENTS AT REPORTING DATE (THOUSANDS) AT SEPT. 30, 2021 QUOTED PRICES SIGNIFICANT SIGNIFICANT AT DEC. 31, 2020 QUOTED PRICES SIGNIFICANT SIGNIFICANT Asset description Institutional money market funds $ 252,807 $ — $ 252,807 $ — $ 86,001 $ — $ 86,001 $ — FTRs 9,338 — — 9,338 4,805 — — 4,805 Natural gas derivatives* 132,892 — 132,892 — 8,599 — 8,599 — Total assets $ 395,037 $ — $ 385,699 $ 9,338 $ 99,405 $ — $ 94,600 $ 4,805 Liability description FTRs $ 1,589 $ — $ — $ 1,589 $ 1,625 $ — $ — $ 1,625 Natural gas derivatives* — — — — 1,612 — 1,612 — Total liabilities $ 1,589 $ — $ — $ 1,589 $ 3,237 $ — $ 1,612 $ 1,625 * Natural gas 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 SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Beginning balance $ 7,501 $ 8,040 $ 3,180 $ 5,778 Unrealized gains (losses)* 3,955 4 18,861 (736) Purchases 619 443 11,426 10,175 Settlements (4,326) (3,160) (25,718) (9,890) Ending balance $ 7,749 $ 5,327 $ 7,749 $ 5,327 * Cleco Power’s unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet. Cleco Cajun’s unrealized gains (losses) 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 September 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 Sept. 30, 2021 $ 9,338 $ 1,589 RTO auction pricing FTR price - per MWh $ (8.18) $ 9.16 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 September 30, 2021, and December 31, 2020: Cleco (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Cash and cash equivalents $ 249,711 $ 80,712 Current restricted cash and cash equivalents $ 2,352 $ 4,545 Non-current restricted cash and cash equivalents $ 744 $ 744
Offsetting Assets	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 September 30, 2021, and December 31, 2020: Cleco DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS AT SEPT. 30, 2021 AT DEC. 31, 2020 GROSS AMOUNTS OFFSET ON THE BALANCE SHEET GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1) (THOUSANDS) BALANCE SHEET LINE ITEM GROSS ASSET (LIABILITY) CONTRACT NETTING COLLATERAL NET ASSET (LIABILITY) ON THE BALANCE SHEET COLLATERAL NET AMOUNT NET ASSET (LIABILITY) ON THE BALANCE SHEET (2) Commodity-related contracts FTRs Current Energy risk management assets $ 9,338 $ — $ — $ 9,338 $ — $ 9,338 $ 4,805 Current Energy risk management liabilities (1,589) — — (1,589) — (1,589) (1,625) Natural gas derivatives Current Energy risk management assets 59,648 (1,283) (8,900) 49,465 (41,098) 8,367 8,276 Non-current Energy risk management assets 83,427 — — 83,427 (13,902) 69,525 323 Current Energy risk management liabilities (1,283) 1,283 — — — — (828) Non-current Other deferred credits — — — — — — (784) Commodity-related contracts, net $ 149,541 $ — $ (8,900) $ 140,641 $ (55,000) $ 85,641 $ 10,167 (1) Represents letters of credit by counterparties. (2) There were no offsetting amounts on or off Cleco’s Condensed Consolidated Balance Sheet at December 31, 2020.
Offsetting Liabilities	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 September 30, 2021, and December 31, 2020: Cleco DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS AT SEPT. 30, 2021 AT DEC. 31, 2020 GROSS AMOUNTS OFFSET ON THE BALANCE SHEET GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1) (THOUSANDS) BALANCE SHEET LINE ITEM GROSS ASSET (LIABILITY) CONTRACT NETTING COLLATERAL NET ASSET (LIABILITY) ON THE BALANCE SHEET COLLATERAL NET AMOUNT NET ASSET (LIABILITY) ON THE BALANCE SHEET (2) Commodity-related contracts FTRs Current Energy risk management assets $ 9,338 $ — $ — $ 9,338 $ — $ 9,338 $ 4,805 Current Energy risk management liabilities (1,589) — — (1,589) — (1,589) (1,625) Natural gas derivatives Current Energy risk management assets 59,648 (1,283) (8,900) 49,465 (41,098) 8,367 8,276 Non-current Energy risk management assets 83,427 — — 83,427 (13,902) 69,525 323 Current Energy risk management liabilities (1,283) 1,283 — — — — (828) Non-current Other deferred credits — — — — — — (784) Commodity-related contracts, net $ 149,541 $ — $ (8,900) $ 140,641 $ (55,000) $ 85,641 $ 10,167 (1) Represents letters of credit by counterparties. (2) There were no offsetting amounts on or off Cleco’s Condensed Consolidated Balance Sheet at December 31, 2020.
Fair Value of Derivative Instruments as Recorded in Condensed Consolidated Balance Sheets	The following table presents the volume of commodity-related derivative contracts outstanding at September 30, 2021, and December 31, 2020, for Cleco and Cleco Power: Cleco TOTAL VOLUME OUTSTANDING (THOUSAND) UNIT OF MEASURE AT SEPT. 30, 2021 AT DEC. 31, 2020 Commodity-related contracts FTRs MWh 22,794 15,269 Natural gas derivatives MMBtus 118,712 73,000
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 nine months ended September 30, 2021, and 2020: Cleco AMOUNT OF GAIN(LOSS) ON DERIVATIVES RECOGNIZED IN INCOME FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) INCOME STATEMENT LINE ITEM 2021 2020 2021 2020 Commodity-related contracts FTRs (1) Electric operations $ 1,959 $ 3,013 $ 11,167 $ 6,262 FTRs (1) Purchased power (874) (763) (8,730) (1,053) Natural gas derivatives Fuel used for electric generation 107,687 20,307 165,584 22,515 Total $ 108,772 $ 22,557 $ 168,021 $ 27,724
CLECO POWER
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Carrying Value and Estimated Fair Value	Cleco Power AT SEPT. 30, 2021 AT DEC. 31, 2020 (THOUSANDS) CARRYING FAIR VALUE CARRYING FAIR VALUE Long-term debt $ 1,820,177 $ 2,100,029 $ 1,494,947 $ 1,794,799 * The carrying value of long-term debt does not include deferred issuance costs of $8.5 million at
Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis	Cleco Power FAIR VALUE MEASUREMENTS AT REPORTING DATE (THOUSANDS) AT SEPT. 30, 2021 QUOTED PRICES IN ACTIVE MARKETS SIGNIFICANT SIGNIFICANT AT DEC. 31, 2020 QUOTED PRICES SIGNIFICANT SIGNIFICANT Asset description Institutional money market funds $ 135,763 $ — $ 135,763 $ — $ 25,357 $ — $ 25,357 $ — FTRs 6,028 — — 6,028 4,337 — — 4,337 Total assets $ 141,791 $ — $ 135,763 $ 6,028 $ 29,694 $ — $ 25,357 $ 4,337 Liability description FTRs $ 1,330 $ — $ — $ 1,330 $ 1,121 $ — $ — $ 1,121 Total liabilities $ 1,330 $ — $ — $ 1,330 $ 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 SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Beginning balance $ 5,990 $ 7,511 $ 3,216 $ 5,725 Unrealized gains* 1,196 426 545 1,355 Purchases 619 443 9,236 8,219 Settlements (3,107) (2,968) (8,299) (9,887) Ending balance $ 4,698 $ 5,412 $ 4,698 $ 5,412 * Unrealized gains 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 Sept. 30, 2021 $ 6,028 $ 1,330 RTO auction pricing FTR price - per MWh $ (3.26) $ 9.16 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 SEPT. 30, 2021 AT DEC. 31, 2020 Cash and cash equivalents $ 133,411 $ 20,812 Current restricted cash and cash equivalents $ 2,352 $ 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 SEPT. 30, 2021 AT DEC. 31, 2020 Commodity-related contracts FTRs Current Energy risk management assets $ 6,028 $ 4,337 Current Energy risk management liabilities (1,330) (1,121) Commodity-related contracts, net $ 4,698 $ 3,216 Cleco Power TOTAL VOLUME OUTSTANDING (THOUSAND) UNIT OF MEASURE AT SEPT. 30, 2021 AT DEC. 31, 2020 Commodity-related contracts FTRs MWh 14,596 9,521
Amount of Gain (Loss) Recognized in Income on Derivatives	Cleco Power AMOUNT OF GAIN(LOSS) ON DERIVATIVES RECOGNIZED IN INCOME FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) INCOME STATEMENT LINE ITEM 2021 2020 2021 2020 Commodity-related contracts FTRs (1) Electric operations $ 1,959 $ 3,013 $ 11,167 $ 6,262 FTRs (1) Purchased power (822) (2,326) (9,236) (4,397) Total $ 1,137 $ 687 $ 1,931 $ 1,865 (1) For the three and nine months ended September 30, 2021, unrealized gains associated with FTRs of $1.2 million and $0.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the three and nine months ended September 30, 2020, unrealized gains associated with FTRs of $0.4 million and $1.4 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

Pension Plan and Employee Ben_2

Pension Plan and Employee Benefits (Tables)	9 Months Ended
	Sep. 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 nine months ended September 30, 2021, and 2020 were as follows: PENSION BENEFITS OTHER BENEFITS FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE THREE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Components of periodic benefit costs Service cost $ 2,629 $ 2,455 $ 629 $ 600 Interest cost 4,667 5,204 317 418 Expected return on plan assets (5,700) (6,244) — — Amortizations Prior period service credit — (15) — — Net loss 5,184 4,073 373 362 Net periodic benefit cost 6,780 5,473 1,319 1,380 Special/contractual termination benefits 3,270 — — — Total benefit cost $ 10,050 $ 5,473 $ 1,319 $ 1,380 PENSION BENEFITS OTHER BENEFITS FOR THE NINE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Components of periodic benefit costs Service cost $ 7,887 $ 7,365 $ 1,819 $ 1,615 Interest cost 14,001 15,612 962 1,238 Expected return on plan assets (17,101) (18,731) — — Amortizations Prior period service credit — (45) — — Net loss 15,553 12,222 1,143 1,042 Net periodic benefit cost 20,340 16,423 3,924 3,895 Special/contractual termination benefits 3,270 — — — Total benefit cost $ 23,610 $ 16,423 $ 3,924 $ 3,895 FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Components of periodic benefit costs Service cost $ 59 $ 100 $ 174 $ 300 Interest cost 634 733 1,903 2,199 Amortizations Prior period service credit (54) (54) (161) (161) Net loss 307 796 921 2,388 Net periodic benefit cost $ 946 $ 1,575 $ 2,837 $ 4,726
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 September 30, 2021, and December 31, 2020, were as follows: Cleco (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current $ 4,463 $ 4,463 Non-current $ 51,306 $ 51,868 Cleco (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current $ 4,703 $ 4,703 Non-current $ 90,880 $ 92,522
Expense of the 401(k) Plan	Cleco’s 401(k) Plan expense for the three and nine months ended September 30, 2021, and 2020 was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 401(k) Plan expense $ 2,512 $ 2,356 $ 7,391 $ 7,509 subsidiaries for the three and nine months ended September 30, 2021, and 2020 was as follows: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 401(k) Plan expense $ 1,185 $ 996 $ 3,511 $ 3,491
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 SEPT. 30, 2021 AT DEC. 31, 2020 Current $ 3,865 $ 3,865 Non-current $ 40,261 $ 40,734 Cleco Power (THOUSANDS) AT SEPT. 30, 2021 AT DEC. 31, 2020 Current $ 711 $ 711 Non-current $ 19,240 $ 19,828

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 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 nine months ended September 30, 2021, and 2020 : Cleco FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, 2021 2020 2021 2020 Effective tax rate 20.3 % 29.4 % 12.4 % 26.8 %
CLECO POWER
Effective Income Tax Rate [Line Items]
Effective Income Tax Rates	Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, 2021 2020 2021 2020 Effective tax rate 1.0 % 33.4 % (0.2) % 28.8 %

Disclosures about Segments (Tab

Disclosures about Segments (Tables)	9 Months Ended
	Sep. 30, 2021
Segment Reporting [Abstract]
Segment Information	Segment Information for the Three Months Ended Sept. 30, 2021 (THOUSANDS) CLECO POWER CLECO CAJUN TOTAL SEGMENTS Revenue Electric operations $ 357,084 $ 107,500 $ 464,584 Other operations 22,779 35,158 57,937 Affiliate revenue 1,380 — 1,380 Electric customer credits (691) — (691) Operating revenue, net $ 380,552 $ 142,658 $ 523,210 Net income $ 56,561 $ 86,744 $ 143,305 Add: Depreciation and amortization 43,526 12,623 (1) 56,149 Less: Interest income 936 4 940 Add: Interest charges 18,509 1,117 19,626 Add: Federal and state income tax expense 548 29,888 30,436 EBITDA $ 118,208 $ 130,368 $ 248,576 (1) Includes $3.6 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 $ 464,584 $ (2,420) $ — $ 462,164 Other operations 57,937 1 (2,217) 55,721 Affiliate revenue 1,380 32,116 (33,496) — Electric customer credits (691) — — (691) Operating revenue, net $ 523,210 $ 29,697 $ (35,713) $ 517,194 Depreciation and amortization $ 56,149 $ 8,189 (1) $ — $ 64,338 Interest income $ 940 $ 43 $ (42) $ 941 Interest charges $ 19,626 $ 15,044 $ (41) $ 34,629 Federal and state income tax expense $ 30,436 $ 133 $ — $ 30,569 Net income (loss) $ 143,305 $ (23,396) $ 1 $ 119,910 (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 $ 288,852 $ 99,956 $ 388,808 Other operations 17,775 31,331 49,106 Affiliate revenue 1,506 — 1,506 Electric customer credits (16,534) — (16,534) Operating revenue, net $ 291,599 $ 131,287 $ 422,886 Net income $ 36,092 $ 38,357 $ 74,449 Add: Depreciation and amortization 40,268 11,344 (1) 51,612 Less: Interest income 789 10 799 Add: Interest charges 18,441 (484) 17,957 Add: Federal and state income tax expense 18,076 12,258 30,334 EBITDA $ 112,088 $ 61,465 $ 173,553 (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 $ 388,808 $ (2,420) $ — $ 386,388 Other operations 49,106 1 (1,510) 47,597 Affiliate revenue 1,506 35,522 (37,028) — Electric customer credits (16,534) — — (16,534) Operating revenue, net $ 422,886 $ 33,103 $ (38,538) $ 417,451 Depreciation and amortization $ 51,612 $ 4,497 (1) $ — $ 56,109 Interest income $ 799 $ 121 $ (10) $ 910 Interest charges $ 17,957 $ 16,115 $ (12) $ 34,060 Federal and state income tax expense (benefit) $ 30,334 $ (5,260) $ 1 $ 25,075 Net income (loss) $ 74,449 $ (14,154) $ 2 $ 60,297 (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 Nine Months Ended Sept. 30, 2021 (THOUSANDS) CLECO POWER CLECO CAJUN TOTAL SEGMENTS Revenue Electric operations $ 887,191 $ 300,415 $ 1,187,606 Other operations 57,674 98,851 156,525 Affiliate revenue 4,259 — 4,259 Electric customer credits (40,429) 244 (40,185) Operating revenue, net $ 908,695 $ 399,510 $ 1,308,205 Net income $ 102,407 $ 153,719 $ 256,126 Add: Depreciation and amortization 126,534 36,614 (2) 163,148 Less: Interest income 2,404 10 2,414 Add: Interest charges 55,392 786 56,178 Add: Federal and state income tax (benefit) expense (219) 52,561 52,342 EBITDA $ 281,710 $ 243,670 $ 525,380 Additions to property, plant, and equipment $ 202,940 $ 5,904 $ 208,844 Equity investment in investees (1) $ 3,822 $ — $ 3,822 Goodwill (1) $ 1,490,797 $ — $ 1,490,797 Total segment assets (1) $ 6,746,838 $ 1,212,968 $ 7,959,806 (1) Balances as of September 30, 2021. (2) Includes $10.0 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(6.9) million of deferred lease revenue amortization as a result of the Cleco Cajun Transaction. 2021 (THOUSANDS) TOTAL SEGMENTS OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 1,187,606 $ (7,260) $ (1) $ 1,180,345 Other operations 156,525 4 (5,752) 150,777 Affiliate revenue 4,259 85,392 (89,651) — Electric customer credits (40,185) — — (40,185) Operating revenue, net $ 1,308,205 $ 78,136 $ (95,404) $ 1,290,937 Depreciation and amortization $ 163,148 $ 17,052 (2) $ (1) $ 180,199 Interest income $ 2,414 $ 100 $ (98) $ 2,416 Interest charges $ 56,178 $ 45,732 $ (98) $ 101,812 Federal and state income tax expense (benefit) $ 52,342 $ (21,357) $ — $ 30,985 Net income (loss) $ 256,126 $ (37,068) $ 1 $ 219,059 Additions to property, plant, and equipment $ 208,844 $ 1,116 $ — $ 209,960 Equity investment in investees (1) $ 3,822 $ 19,099 $ (19,099) $ 3,822 Goodwill (1) $ 1,490,797 $ — $ — $ 1,490,797 Total segment assets (1) $ 7,959,806 $ 685,410 $ (249,409) $ 8,395,807 (1) Balances as of September 30, 2021. (2) Includes $7.3 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 $ 752,925 $ 273,836 $ 1,026,761 Other operations 49,443 92,928 142,371 Affiliate revenue 3,852 204 4,056 Electric customer credits (33,974) (153) (34,127) Operating revenue, net $ 772,246 $ 366,815 $ 1,139,061 Net income $ 76,156 $ 84,655 $ 160,811 Add: Depreciation and amortization 125,541 33,385 (2) 158,926 Less: Interest income 2,498 269 2,767 Add: Interest charges 55,624 (353) 55,271 Add: Federal and state income tax expense 30,770 27,280 58,050 EBITDA $ 285,593 $ 144,698 $ 430,291 Additions to property, plant, and equipment $ 205,765 $ 7,908 $ 213,673 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 $9.3 million of amortization of intangible assets and liabilities related to wholesale power supply agreements and $(6.9) million deferred lease revenue amortization as a result of the Cleco Cajun Transaction. 2020 (THOUSANDS) TOTAL SEGMENTS OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 1,026,761 $ (7,260) $ — $ 1,019,501 Other operations 142,371 2 (4,966) 137,407 Affiliate revenue 4,056 93,938 (97,994) — Electric customer credits (34,127) — 1 (34,126) Operating revenue, net $ 1,139,061 $ 86,680 $ (102,959) $ 1,122,782 Depreciation and amortization $ 158,926 $ 13,575 (2) $ 1 $ 172,502 Interest income $ 2,767 $ 276 $ (79) $ 2,964 Interest charges $ 55,271 $ 48,731 $ (79) $ 103,923 Federal and state income tax expense (benefit) $ 58,050 $ (17,821) $ 1 $ 40,230 Net income (loss) $ 160,811 $ (51,019) $ 1 $ 109,793 Additions to property, plant, and equipment $ 213,673 $ 2,019 $ — $ 215,692 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 $7.3 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 SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Net income $ 119,910 $ 60,297 $ 219,059 $ 109,793 Add: Depreciation and amortization 64,338 56,109 180,199 172,502 Less: Interest income 941 910 2,416 2,964 Add: Interest charges 34,629 34,060 101,812 103,923 Add: Federal and state income tax expense 30,569 25,075 30,985 40,230 Add: Other corporate costs and noncash items (1) 71 (1,078) (4,259) 6,807 Total segment EBITDA $ 248,576 $ 173,553 $ 525,380 $ 430,291 (1) Adjustments made for Other and Elimination totals not allocated to total segment EBITDA.

Regulation and Rates (Tables)

Regulation and Rates (Tables)	9 Months Ended
	Sep. 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 SEPT. 30, 2021 AT DEC. 31, 2020 Cleco Katrina/Rita storm recovery charges $ 1,610 $ 1,617 FERC audit $ — $ 1,912 FRP $ 1,236 $ 1,786 Site-specific industrial customer $ 611 $ 710 TCJA $ 2,057 $ 2,057 Transmission ROE $ — $ 595

Variable Interest Entities (Tab

Variable Interest Entities (Tables) - CLECO POWER	9 Months Ended
	Sep. 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 SEPT. 30, 2021 AT DEC. 31, 2020 Purchase price $ 12,873 $ 12,873 Cash contributions 6,399 6,399 Distributions (15,450) (10,200) Total equity investment in investee $ 3,822 $ 9,072 The following table contains summarized financial information for Oxbow: FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Operating revenue $ 1,486 $ 2,275 $ 5,113 $ 33,266 Operating expenses 1,486 2,275 5,113 33,266 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 SEPT. 30, 2021 AT DEC. 31, 2020 Oxbow’s net assets/liabilities $ 7,645 $ 18,145 Cleco Power’s 50% equity $ 3,822 $ 9,072 Cleco Power’s maximum exposure to loss $ 3,822 $ 9,072

Litigation, Other Commitments_2

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees (Tables)	9 Months Ended
	Sep. 30, 2021
Commitments and Contingencies Disclosure [Abstract]
Schedule of Change in Asset Retirement Obligation	The following tables summarize the net changes in the ARO for Cleco and Cleco Power: (THOUSANDS) CLECO CAJUN CLECO POWER CLECO Balance, Dec. 31, 2020 $ 16,658 $ 11,364 $ 28,022 Liabilities settled (1,316) $ — (1,316) Accretion 466 $ 249 715 Revisions and adjustments 35,540 $ 13,101 48,641 Balance, Sept. 30, 2021 $ 51,348 $ 24,714 $ 76,062

Affiliate Transactions (Tables)

Affiliate Transactions (Tables)	9 Months Ended
	Sep. 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 SEPT. 30, 2021 AT DEC. 31, 2020 (THOUSANDS) ACCOUNTS ACCOUNTS ACCOUNTS ACCOUNTS Cleco Holdings $ 10,712 $ 57,825 $ 10,353 $ 57,713 Support Group 2,388 11,514 3,248 14,355 Cleco Cajun 882 17 1,004 — Total $ 13,982 $ 69,356 $ 14,605 $ 72,068

Intangible Assets and Liabili_2

Intangible Assets and Liabilities (Tables)	9 Months Ended
	Sep. 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 SEPT. 30, FOR THE NINE MONTHS ENDED SEPT. 30, (THOUSANDS) 2021 2020 2021 2020 Intangible assets Cleco Katrina/Rita right to bill and collect storm recovery charges $ — $ — $ — $ 517 Trade name $ 3,770 $ 64 $ 3,897 $ 191 Power supply agreements $ 6,400 $ 6,400 $ 19,200 $ 19,200 Intangible liabilities LTSA $ 871 $ 871 $ 2,613 $ 2,613 Power supply agreements $ 389 $ 882 $ 1,989 $ 2,646
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 SEPT. 30, 2021 AT DEC. 31, 2020 Intangible assets Trade name $ — $ 5,100 Power supply agreements 184,004 184,004 Total intangible assets carrying amount 184,004 189,104 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 145,704 150,804 Accumulated amortization (77,326) (63,932) Net intangible assets subject to amortization $ 68,378 $ 86,872 Goodwill On April 13, 2016, in connection with the completion of the 2016 Merger, Cleco recognized goodwill of $1.49 billion. Management assigned the recognized goodwill to the Cleco Power reporting unit. Goodwill is required to be tested for impairment at the reporting unit level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying value. Application of the goodwill impairment test requires significant judgments, including the identification of reporting units, assignments of assets and liabilities to reporting units, assignment of goodwill to reporting units, and the determination of the fair value of the reporting units. Cleco conducted its 2021 annual impairment test using an August 1, 2021, measurement date. The fair value of the Cleco Power reporting unit was estimated using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market
CLECO POWER
Finite-Lived Intangible Assets [Line Items]
Schedule of Amortization of Intangible Assets and Liabilities	Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, FOR THE NINE MONTHS (THOUSANDS) 2021 2020 2021 2020 Cleco Katrina/Rita right to bill and collect storm recovery charges $ — $ — $ — $ 517

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Loss (Tables)	9 Months Ended
	Sep. 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 FOR THE NINE (THOUSANDS) POSTRETIREMENT BENEFIT NET LOSS Balances, beginning of period $ (25,588) $ (25,796) Amounts reclassified from AOCI Amortization of postretirement benefit net loss 96 304 Balances, Sept. 30, 2021 $ (25,492) $ (25,492) FOR THE THREE MONTHS ENDED FOR THE NINE MONTHS ENDED (THOUSANDS) POSTRETIREMENT BENEFIT NET LOSS Balances, beginning of period $ (16,657) $ (17,513) Amounts reclassified from AOCI Amortization of postretirement benefit net loss 448 1,304 Balances, Sept. 30, 2020 $ (16,209) $ (16,209)
CLECO POWER
Accumulated Other Comprehensive Loss [Line Items]
Schedule of Accumulated Other Comprehensive Income Loss	Cleco Power FOR THE THREE MONTHS ENDED SEPT. 30, 2021 FOR THE NINE MONTHS ENDED SEPT. 30, 2021 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (18,394) $ (5,486) $ (23,880) $ (19,139) $ (5,614) $ (24,753) Amounts reclassified from AOCI Amortization of postretirement benefit net loss 350 — 350 1,095 — 1,095 Reclassification of net loss to interest charges — 63 63 — 191 191 Balances, Sept. 30, 2021 $ (18,044) $ (5,423) $ (23,467) $ (18,044) $ (5,423) $ (23,467) FOR THE THREE MONTHS ENDED SEPT. 30, 2020 FOR THE NINE MONTHS ENDED SEPT. 30, 2020 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (15,872) $ (5,740) $ (21,612) $ (16,717) $ (5,868) $ (22,585) Amounts reclassified from AOCI Amortization of postretirement benefit net loss 373 — 373 1,218 — 1,218 Reclassification of net loss to interest charges — 63 63 — 191 191 Balances, Sept. 30, 2020 $ (15,499) $ (5,677) $ (21,176) $ (15,499) $ (5,677) $ (21,176)

Summary of Significant Accoun_4

Summary of Significant Accounting Policies - Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Restricted Cash and Cash Equivalents Items [Line Items]
Current	$ 2,352	$ 4,545
Non-current	745	744
Total restricted cash and cash equivalents	3,097	5,289
CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	2,352	4,545
Total restricted cash and cash equivalents	2,352	4,545
Cleco Katrina/Rita storm recovery surcharge
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,674	2,626
Cleco Katrina/Rita storm recovery surcharge | CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,674	2,626
Charitable contributions
Restricted Cash and Cash Equivalents Items [Line Items]
Current	678	1,718
Charitable contributions | CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	678	1,718
Rate credit escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Current	0	201
Rate credit escrow | CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	0	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	$ 723	$ 722

Summary of Significant Accoun_5

Summary of Significant Accounting Policies - Additional Information (Details) - CLECO POWER - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Regulatory Assets [Line Items]
Regulatory assets	$ 721,426	$ 456,034
COVID-19 executive order
Regulatory Assets [Line Items]
Regulatory assets	$ 2,953	$ 2,953

Summary of Significant Accoun_6

Summary of Significant Accounting Policies - Changes in Allowance for Credit Losses (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 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	$ 1,334	$ 3,486	$ 2,758	$ 3,005
Current period provision	567	2,041	3,057	5,675
Charge-offs	(730)	0	(5,172)	(4,091)
Recovery	586	54	1,114	921
Accounts receivable, ending balance	1,757	5,581	1,757	5,581
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
TOTAL
Total, beginning balance	2,972	5,124	4,396	4,255
Current period provision	567	2,041	3,057	6,063
Charge-offs	(730)	0	(5,172)	(4,091)
Recovery	586	54	1,114	921
Total, ending balance	3,395	7,219	3,395	7,219
CLECO POWER
ACCOUNTS RECEIVABLE
Accounts receivable, beginning balance	1,334	3,486	2,758	3,005
Current period provision	567	2,041	3,057	5,675
Charge-offs	(730)	0	(5,172)	(4,091)
Recovery	586	54	1,114	921
Accounts receivable, ending balance	$ 1,757	5,581	$ 1,757	5,581
Accounting Standards Update 2016-13 | CECL adoption
ACCOUNTS RECEIVABLE
Accounts receivable, beginning balance		0		71
TOTAL
Total, beginning balance		0		71
Accounting Standards Update 2016-13 | CLECO POWER | CECL adoption
ACCOUNTS RECEIVABLE
Accounts receivable, beginning balance		$ 0		$ 71

Leases - Narrative (Details)

Leases - Narrative (Details) $ in Millions	Sep. 30, 2021USD ($)
Cottonwood Energy
Lessor, Lease, Description [Line Items]
Fixed lease payments per year	$ 40

Leases - Lease Income Under Cot

Leases - Lease Income Under Cottonwood Sale Leaseback (Details) - Cleco Cajun - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Lessor, Lease, Description [Line Items]
Fixed payments	$ 10,000	$ 10,000	$ 30,000	$ 30,000
Variable payments	4,938	5,190	15,413	15,950
Amortization of deferred lease liability	2,301	2,301	6,904	6,904
Total lease income	$ 17,239	$ 17,491	$ 52,317	$ 52,854

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 498,845	$ 396,924	$ 1,228,618	$ 1,063,613
Revenue unrelated to contracts with customers
Other	18,349	20,527	62,319	59,169
Total revenue unrelated to contracts with customers	18,349	20,527	62,319	59,169
Operating revenue, net	517,194	417,451	1,290,937	1,122,782
Electric customer credits	691	16,534	40,185	34,126
Deferred lease amortization			6,904	6,904
Total retail revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	280,394	217,090	653,675	573,294
Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	148,522	128,981	348,918	308,525
Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	82,711	68,220	214,129	190,905
Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	45,446	32,809	119,497	94,227
Other retail
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	4,479	3,614	11,925	10,416
Surcharge
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers				2,440
Electric customer credits
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(764)	(16,534)	(40,794)	(33,219)
Wholesale, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	179,912	149,752	475,924	406,715
Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	32,921	26,964	85,511	73,187
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	5,618	3,118	13,508	10,417
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	45,400	46,000
Deferred lease amortization	2,300	2,300	6,900	6,900
OPERATING SEGMENTS
Revenue unrelated to contracts with customers
Operating revenue, net	523,210	422,886	1,308,205	1,139,061
Electric customer credits	691	16,534	40,185	34,127
OPERATING SEGMENTS | CLECO POWER
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	379,458	288,586	898,742	765,974
Revenue unrelated to contracts with customers
Other	1,094	3,013	9,953	6,272
Total revenue unrelated to contracts with customers	1,094	3,013	9,953	6,272
Operating revenue, net	380,552	291,599	908,695	772,246
Electric customer credits	691	16,534	40,429	33,974
OPERATING SEGMENTS | CLECO POWER | Total retail revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	280,394	217,090	653,675	573,294
OPERATING SEGMENTS | CLECO POWER | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	148,522	128,981	348,918	308,525
OPERATING SEGMENTS | CLECO POWER | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	82,711	68,220	214,129	190,905
OPERATING SEGMENTS | CLECO POWER | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	45,446	32,809	119,497	94,227
OPERATING SEGMENTS | CLECO POWER | Other retail
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	4,479	3,614	11,925	10,416
OPERATING SEGMENTS | CLECO POWER | Surcharge
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers				2,440
OPERATING SEGMENTS | CLECO POWER | Electric customer credits
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(764)	(16,534)	(40,794)	(33,219)
OPERATING SEGMENTS | CLECO POWER | Wholesale, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	74,831	52,216	182,769	140,139
OPERATING SEGMENTS | CLECO POWER | Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	17,235	14,656	44,530	38,273
Revenue unrelated to contracts with customers
Electric customer credits	100		400	800
OPERATING SEGMENTS | CLECO POWER | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	5,618	3,118	13,509	10,416
OPERATING SEGMENTS | CLECO POWER | Affiliate
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,380	1,506	4,259	3,852
OPERATING SEGMENTS | CLECO CAJUN
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	125,404	113,774	347,148	313,920
Revenue unrelated to contracts with customers
Other	17,254	17,513	52,362	52,895
Total revenue unrelated to contracts with customers	17,254	17,513	52,362	52,895
Operating revenue, net	142,658	131,287	399,510	366,815
Electric customer credits	0	0	(244)	153
Lease revenue	14,900
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	107,501	99,956	300,415	273,836
OPERATING SEGMENTS | CLECO CAJUN | Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	17,903	13,818	46,733	39,880
Revenue unrelated to contracts with customers
Electric customer credits			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	0	0	204
OTHER
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	29,696	33,102	78,132	86,678
Revenue unrelated to contracts with customers
Other	1	1	4	2
Total revenue unrelated to contracts with customers	1	1	4	2
Operating revenue, net	29,697	33,103	78,136	86,680
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)	(7,260)	(7,260)
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	32,116	35,522	85,392	93,938
ELIMINATIONS
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(35,713)	(38,538)	(95,404)	(102,959)
Revenue unrelated to contracts with customers
Other	0	0	0	0
Total revenue unrelated to contracts with customers	0	0	0	0
Operating revenue, net	(35,713)	(38,538)	(95,404)	(102,959)
Electric customer credits	0	0	0	(1)
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	0
ELIMINATIONS | Transmission, net
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	(2,217)	(1,510)	(5,752)	(4,966)
ELIMINATIONS | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0	(1)	1
ELIMINATIONS | Affiliate
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ (33,496)	$ (37,028)	$ (89,651)	$ (97,994)

Revenue Recognition - Narrative

Revenue Recognition - Narrative (Details) $ in Millions	Sep. 30, 2021USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied performance obligations	$ 65.7
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-10-01 | 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]: 2021-10-01 | Maximum
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Unsatisfied performance obligation durations	14 years

Regulatory Assets and Liabili_3

Regulatory Assets and Liabilities - Schedule of Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Jun. 16, 2021	Dec. 31, 2020
Regulatory Assets [Line Items]
Total regulatory assets, net	$ 716,322		$ 423,279
Financing costs
Regulatory Assets [Line Items]
Regulatory assets	7,334		7,592
Postretirement costs
Regulatory Assets [Line Items]
Regulatory assets	13,921		15,411
Fair value of long-term debt
Regulatory Assets [Line Items]
Regulatory assets	114,001		119,553
Debt issuance costs
Regulatory Assets [Line Items]
Regulatory assets	5,004		5,254
CLECO POWER
Regulatory Assets [Line Items]
Regulatory assets	721,426		456,034
Regulatory liabilities	(145,364)		(180,565)
Total regulatory assets, net	576,062		275,469
CLECO POWER | Acquisition/ transaction costs
Regulatory Assets [Line Items]
Regulatory assets	$ 1,939		2,019
Regulatory asset, amortization period	18 years 6 months
CLECO POWER | Acquisition/ transaction costs | Coughlin transaction costs
Regulatory Assets [Line Items]
Regulatory assets	$ 853		876
Regulatory asset, amortization period	28 years
CLECO POWER | Accumulated deferred fuel
Regulatory Assets [Line Items]
Regulatory assets	$ 78,847		28,194
CLECO POWER | AFUDC equity gross-up
Regulatory Assets [Line Items]
Regulatory assets	67,348		69,670
CLECO POWER | Affordability study
Regulatory Assets [Line Items]
Regulatory assets	$ 13,438	$ 13,600	0
Regulatory asset, amortization period	10 years
CLECO POWER | AMI deferred revenue requirement
Regulatory Assets [Line Items]
Regulatory assets	$ 2,181		2,591
Regulatory asset, amortization period	4 years
CLECO POWER | AROs
Regulatory Assets [Line Items]
Regulatory assets	$ 8,060		5,488
CLECO POWER | Bayou Vista to Segura deferred revenue requirement
Regulatory Assets [Line Items]
Regulatory assets	287	$ 300	0
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	17,866		17,051
CLECO POWER | Deferred storm restoration costs - Hurricane Ida
Regulatory Assets [Line Items]
Regulatory assets	36,836		0
CLECO POWER | Deferred storm restoration costs - Hurricane Laura
Regulatory Assets [Line Items]
Regulatory assets	56,815		54,406
CLECO POWER | Deferred storm restoration costs - Hurricane Zeta
Regulatory Assets [Line Items]
Regulatory assets	3,496		3,493
CLECO POWER | Deferred storm restoration costs - Winter Storms Uri & Viola
Regulatory Assets [Line Items]
Regulatory assets	1,974		0
CLECO POWER | Station closure costs | Dolet Hills
Regulatory Assets [Line Items]
Regulatory assets	112,158		48,982
CLECO POWER | Emergency declarations
Regulatory Assets [Line Items]
Regulatory assets	0		270
CLECO POWER | Energy efficiency
Regulatory Assets [Line Items]
Regulatory assets	$ 1,998		2,820
Regulatory asset, amortization period	1 year 6 months
CLECO POWER | Financing costs
Regulatory Assets [Line Items]
Regulatory assets	$ 6,919		7,184
CLECO POWER | Interest costs
Regulatory Assets [Line Items]
Regulatory assets	3,521		3,708
CLECO POWER | Mine closure costs | Lignite Mine
Regulatory Assets [Line Items]
Regulatory assets	93,093		0
CLECO POWER | Madison Unit 3 property taxes
Regulatory Assets [Line Items]
Regulatory assets	6,272		0
CLECO POWER | Non-service cost of postretirement benefits
Regulatory Assets [Line Items]
Regulatory assets	11,662		9,901
CLECO POWER | Other
Regulatory Assets [Line Items]
Regulatory assets	13,247		4,229
CLECO POWER | Postretirement costs
Regulatory Assets [Line Items]
Regulatory assets	149,883		165,437
CLECO POWER | Production operations and maintenance expenses
Regulatory Assets [Line Items]
Regulatory assets	1,998		4,058
CLECO POWER | Rodemacher Unit 2 deferred costs | Rodemacher Unit 2 deferred costs
Regulatory Assets [Line Items]
Regulatory assets	5,519		1,333
CLECO POWER | St. Mary Clean Energy Center
Regulatory Assets [Line Items]
Regulatory assets	$ 6,524		3,479
Regulatory asset, amortization period	4 years
CLECO POWER | Training costs
Regulatory Assets [Line Items]
Regulatory assets	$ 5,968		6,085
Regulatory asset, amortization period	38 years 6 months
CLECO POWER | Tree trimming costs
Regulatory Assets [Line Items]
Regulatory assets	$ 9,771		11,807
Regulatory asset, amortization period	3 years 6 months
CLECO POWER | AFUDC
Regulatory Assets [Line Items]
Regulatory liabilities	$ (6,500)		(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	$ (138,864)		$ (175,584)

Regulatory Assets and Liabili_4

Regulatory Assets and Liabilities - Narrative (Details) - CLECO POWER customer in Thousands, $ in Thousands	Jul. 01, 2022	Jul. 01, 2021	May 31, 2021	Sep. 30, 2021USD ($)	Aug. 29, 2021customer	Jun. 30, 2021USD ($)	Jun. 16, 2021USD ($)	Mar. 29, 2021USD ($)	Feb. 17, 2021customer	Feb. 14, 2021customer	Dec. 31, 2020USD ($)
Regulatory Liabilities [Line Items]
Regulatory assets				$ 721,426							$ 456,034
Affordability study
Regulatory Liabilities [Line Items]
Regulatory assets				13,438			$ 13,600				0
Regulatory asset, amortization period		10 years
Bayou Vista to Segura deferred revenue requirement
Regulatory Liabilities [Line Items]
Regulatory assets				287			$ 300				0
Bayou Vista to Segura deferred revenue requirement | Subsequent event | Forecast
Regulatory Liabilities [Line Items]
Regulatory asset, amortization period	12 months
Mine closure costs | Lignite Mine
Regulatory Liabilities [Line Items]
Regulatory assets				93,093							0
Madison Unit 3 property taxes
Regulatory Liabilities [Line Items]
Regulatory assets				$ 6,272							0
Regulatory asset, amortization period				12 months
Northlake Transmission Agreement, under collection
Regulatory Liabilities [Line Items]
Regulatory assets				$ 4,200		$ 5,700
Regulatory asset, amortization period		12 months
Other deferred costs, primarily base rate case
Regulatory Liabilities [Line Items]
Regulatory assets				3,900
Regulatory asset, amortization period		4 years
Coughlin Pipeline Project, deferred revenue
Regulatory Liabilities [Line Items]
Regulatory assets				5,100
Regulatory asset, amortization period		4 years
St. Mary Clean Energy Center
Regulatory Liabilities [Line Items]
Regulatory assets				6,524							$ 3,479
Regulatory asset, amortization period		4 years
Deferred storm restoration costs - Hurricane Ida
Regulatory Liabilities [Line Items]
Capitalized storm restoration costs				49,100
Number of customers affected with power outage | customer					100
Deferred storm restoration costs - Winter Storms Uri & Viola
Regulatory Liabilities [Line Items]
Capitalized storm restoration costs				$ 8,400				$ 50,000
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

Fair Value Accounting and Fin_3

Fair Value Accounting and Financial Instruments - Carrying Value and Estimated Fair Value (Details) - USD ($) $ in Thousands	Sep. 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	$ 14,100	$ 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	8,500	7,000
CARRYING VALUE
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	3,550,179	3,230,500
CARRYING VALUE | CLECO POWER
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,820,177	1,494,947
FAIR VALUE
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	3,836,960	3,541,349
FAIR VALUE | CLECO POWER
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 2,100,029	$ 1,794,799

Fair Value Accounting and Fin_4

Fair Value Accounting and Financial Instruments - Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis (Details) - Measured on a Recurring Basis - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Asset description
Institutional money market funds	$ 252,807	$ 86,001
Total assets	395,037	99,405
Liability description
Total liabilities	1,589	3,237
CLECO POWER
Asset description
Institutional money market funds	135,763	25,357
Total assets	141,791	29,694
Liability description
Total liabilities	1,330	1,121
FTRs
Asset description
Derivative assets	9,338	4,805
Liability description
Derivative liabilities	1,589	1,625
FTRs | CLECO POWER
Asset description
Derivative assets	6,028	4,337
Liability description
Derivative liabilities	1,330	1,121
Natural gas derivatives*
Asset description
Derivative assets	132,892	8,599
Liability description
Derivative liabilities	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
Derivative assets	0	0
Liability description
Derivative liabilities	0	0
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | FTRs | CLECO POWER
Asset description
Derivative assets	0	0
Liability description
Derivative liabilities	0	0
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | Natural gas derivatives*
Asset description
Derivative assets	0	0
Liability description
Derivative liabilities	0	0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)
Asset description
Institutional money market funds	252,807	86,001
Total assets	385,699	94,600
Liability description
Total liabilities	0	1,612
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | CLECO POWER
Asset description
Institutional money market funds	135,763	25,357
Total assets	135,763	25,357
Liability description
Total liabilities	0	0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | FTRs
Asset description
Derivative assets	0	0
Liability description
Derivative liabilities	0	0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | FTRs | CLECO POWER
Asset description
Derivative assets	0	0
Liability description
Derivative liabilities	0	0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | Natural gas derivatives*
Asset description
Derivative assets	132,892	8,599
Liability description
Derivative liabilities	0	1,612
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset description
Institutional money market funds	0	0
Derivative assets	9,338	4,805
Total assets	9,338	4,805
Liability description
Derivative liabilities	1,589	1,625
Total liabilities	1,589	1,625
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | CLECO POWER
Asset description
Institutional money market funds	0	0
Derivative assets	6,028	4,337
Total assets	6,028	4,337
Liability description
Derivative liabilities	1,330	1,121
Total liabilities	1,330	1,121
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | FTRs
Asset description
Derivative assets	9,338	4,805
Liability description
Derivative liabilities	1,589	1,625
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | FTRs | CLECO POWER
Asset description
Derivative assets	6,028	4,337
Liability description
Derivative liabilities	1,330	1,121
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | Natural gas derivatives*
Asset description
Derivative assets	0	0
Liability description
Derivative liabilities	$ 0	$ 0

Fair Value Accounting and Fin_5

Fair Value Accounting and Financial Instruments - Net Changes in Net Fair Value of FTR Assets and Liabilities Classified as Level 3 (Details) - Price risk derivatives - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 7,501	$ 8,040	$ 3,180	$ 5,778
Unrealized gains (losses)	3,955	4	18,861	(736)
Purchases	619	443	11,426	10,175
Settlements	(4,326)	(3,160)	(25,718)	(9,890)
Ending balance	7,749	5,327	7,749	5,327
CLECO POWER
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	5,990	7,511	3,216	5,725
Unrealized gains (losses)	1,196	426	545	1,355
Purchases	619	443	9,236	8,219
Settlements	(3,107)	(2,968)	(8,299)	(9,887)
Ending balance	$ 4,698	$ 5,412	$ 4,698	$ 5,412

Fair Value Accounting and Fin_6

Fair Value Accounting and Financial Instruments - Significant Unobservable Inputs Used in Developing Fair Value of Level 3 Positions (Details) - Measured on a Recurring Basis - Level 3 $ in Thousands	Sep. 30, 2021USD ($)$ / MW	Dec. 31, 2020USD ($)$ / MW
FAIR VALUE
ASSETS | $	$ 9,338	$ 4,805
LIABILITIES | $	1,589	1,625
CLECO POWER
FAIR VALUE
ASSETS | $	6,028	4,337
LIABILITIES | $	$ 1,330	$ 1,121
Minimum
FAIR VALUE
FORWARD PRICE RANGE (usd per mwh) | $ / MW	(8.18)	(3.49)
Minimum | CLECO POWER
FAIR VALUE
FORWARD PRICE RANGE (usd per mwh) | $ / MW	(3.26)	(3.34)
Maximum
FAIR VALUE
FORWARD PRICE RANGE (usd per mwh) | $ / MW	9.16	4.36
Maximum | CLECO POWER
FAIR VALUE
FORWARD PRICE RANGE (usd per mwh) | $ / MW	9.16	4.36

Fair Value Accounting and Fin_7

Fair Value Accounting and Financial Instruments - Additional Information (Details) MWh in Thousands, MMBTU in Thousands	9 Months Ended			12 Months Ended
	Sep. 30, 2021USD ($)	Sep. 30, 2021USD ($)MWh	Sep. 30, 2021USD ($)MMBTU	Dec. 31, 2020USD ($)MWh	Dec. 31, 2020USD ($)MMBTU
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Intangible assets	$ 88,635,000	$ 88,635,000	$ 88,635,000	$ 111,731,000	$ 111,731,000
Volume outstanding		22,794	118,712	15,269	73,000
Trade name
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Impairment of intangible assets	3,800,000
Intangible assets	$ 0	$ 0	$ 0
Trade name | Level 3 | Average rate | Discounted Cash Flow
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Measurement input	0.08	0.08	0.08
CLECO POWER
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Volume outstanding | MWh		14,596		9,521
Energy risk management assets, current | Natural gas derivatives* | DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Collateral	$ 8,900,000	$ 8,900,000	$ 8,900,000	$ 0	$ 0

Fair Value Accounting and Fin_8

Fair Value Accounting and Financial Instruments - Institutional Money Market Funds (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 249,711	$ 80,712
CLECO POWER
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Cash and cash equivalents	133,411	20,812
Current restricted cash and cash equivalents
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Restricted cash and cash equivalents	2,352	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	2,352	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

Fair Value Accounting and Fin_9

Fair Value Accounting and Financial Instruments - Fair Value of Derivative Instruments as Recorded in Condensed Consolidated Balance Sheets (Details) - DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS - USD ($)	Sep. 30, 2021	Dec. 31, 2020
GROSS ASSET (LIABILITY)
Commodity-related contracts, net	$ 149,541,000
GROSS AMOUNTS OFFSET ON THE BALANCE SHEET
Derivative, contract netting	0
Derivative, collateral total	(8,900,000)
NET ASSET (LIABILITY) ON THE BALANCE SHEET
Net asset (liability) on the balance sheet	140,641,000	$ 10,167,000
GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1)
Collateral, assets	(55,000,000)
NET AMOUNT
Net amount	85,641,000
Price risk derivatives | CLECO POWER
GROSS ASSET (LIABILITY)
Commodity-related contracts, net	4,698,000	3,216,000
Price risk derivatives | Energy risk management assets, current
GROSS ASSET (LIABILITY)
Derivative asset	9,338,000
GROSS AMOUNTS OFFSET ON THE BALANCE SHEET
Derivative asset, contract netting	0
Derivative asset, collateral	0
NET ASSET (LIABILITY) ON THE BALANCE SHEET
Derivative asset	9,338,000	4,805,000
GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1)
Collateral, assets	0
NET AMOUNT
Derivative asset, net	9,338,000
Price risk derivatives | Energy risk management assets, current | CLECO POWER
GROSS ASSET (LIABILITY)
Derivative asset	6,028,000	4,337,000
Price risk derivatives | Energy risk management liabilities
GROSS ASSET (LIABILITY)
Derivative liability	(1,589,000)
GROSS AMOUNTS OFFSET ON THE BALANCE SHEET
Derivative liability, contract netting	0
Derivative liability, collateral	0
NET ASSET (LIABILITY) ON THE BALANCE SHEET
Derivative liability	(1,589,000)	(1,625,000)
GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1)
Collateral, liability	0
NET AMOUNT
Derivative liability, net	(1,589,000)
Price risk derivatives | Energy risk management liabilities | CLECO POWER
GROSS ASSET (LIABILITY)
Derivative liability	(1,330,000)	(1,121,000)
Natural gas derivatives* | Energy risk management assets, current
GROSS ASSET (LIABILITY)
Derivative asset	59,648,000
GROSS AMOUNTS OFFSET ON THE BALANCE SHEET
Derivative asset, contract netting	(1,283,000)
Derivative asset, collateral	(8,900,000)	0
NET ASSET (LIABILITY) ON THE BALANCE SHEET
Derivative asset	49,465,000	8,276,000
GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1)
Collateral, assets	(41,098,000)
NET AMOUNT
Derivative asset, net	8,367,000
Natural gas derivatives* | Energy risk management liabilities
GROSS ASSET (LIABILITY)
Derivative liability	(1,283,000)
GROSS AMOUNTS OFFSET ON THE BALANCE SHEET
Derivative liability, contract netting	1,283,000
Derivative liability, collateral	0
NET ASSET (LIABILITY) ON THE BALANCE SHEET
Derivative liability	0	(828,000)
GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1)
Collateral, liability	0
NET AMOUNT
Derivative liability, net	0
Natural gas derivatives* | Energy risk management assets, noncurrent
GROSS ASSET (LIABILITY)
Derivative asset	83,427,000
GROSS AMOUNTS OFFSET ON THE BALANCE SHEET
Derivative asset, contract netting	0
Derivative asset, collateral	0
NET ASSET (LIABILITY) ON THE BALANCE SHEET
Derivative asset	83,427,000	323,000
GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1)
Collateral, assets	(13,902,000)
NET AMOUNT
Derivative asset, net	69,525,000
Natural gas derivatives* | Other deferred credits
GROSS ASSET (LIABILITY)
Derivative liability	0
GROSS AMOUNTS OFFSET ON THE BALANCE SHEET
Derivative liability, contract netting	0
Derivative liability, collateral	0
NET ASSET (LIABILITY) ON THE BALANCE SHEET
Derivative liability	0	$ (784,000)
GROSS AMOUNTS NOT OFFSET ON THE BALANCE SHEET (1)
Collateral, liability	0
NET AMOUNT
Derivative liability, net	$ 0

Fair Value Accounting and Fi_10

Fair Value Accounting and Financial Instruments - Amount of Gain (Loss) Recognized in Income on Derivatives (Details) - DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS - Price risk derivatives - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	$ 108,772	$ 22,557	$ 168,021	$ 27,724
Accumulated deferred fuel
Commodity-related contracts
Unrealized gains (losses) associated with FTRs	1,200	400	500	1,400
CLECO POWER
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	1,137	687	1,931	1,865
CLECO POWER | Accumulated deferred fuel
Commodity-related contracts
Unrealized gains (losses) associated with FTRs	1,200	400	500	1,400
Electric operations
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	1,959	3,013	11,167	6,262
Electric operations | CLECO POWER
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	1,959	3,013	11,167	6,262
Purchased power
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	(874)	(763)	(8,730)	(1,053)
Purchased power | CLECO POWER
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	(822)	(2,326)	(9,236)	(4,397)
Fuel used for electric generation
Commodity-related contracts
Net gain (loss) recognized in income on derivatives	$ 107,687	$ 20,307	$ 165,584	$ 22,515

Debt (Details)

Debt (Details)	Sep. 10, 2021USD ($)	May 21, 2021USD ($)	Sep. 30, 2021USD ($)
Line of credit | Revolving credit agreement
Debt [Line Items]
Debt, face amount		$ 175,000,000
Ratio of indebtedness		0.65
Commitment fees		0.275%
Potential additional interest		0.125%
Potential additional commitment fee		0.05%
Borrowings outstanding			$ 0
Term loan
Debt [Line Items]
Debt, face amount		$ 266,000,000
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
Ratio of indebtedness		0.65
Commitment fees		0.15%
Potential additional interest		0.125%
Potential additional commitment fee		0.025%
Borrowings outstanding			$ 0
CLECO POWER | Term loan
Debt [Line Items]
Debt, face amount		$ 125,000,000
CLECO POWER | Senior Notes
Debt [Line Items]
Debt, face amount	$ 325,000,000
Redemption price percentage	100.00%
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 | LIBOR | Senior Notes
Debt [Line Items]
Basis spread on variable rate	0.50%
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%

Pension Plan and Employee Ben_3

Pension Plan and Employee Benefits - Narrative (Details) - USD ($)	Mar. 11, 2021	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Pension Plan
Defined Benefit Plan Disclosure [Line Items]
Pension contributions required through 2025	$ 0
Special/contractual termination benefits, percent increase in benefits		10.00%		10.00%
Special/contractual termination benefits		$ 3,270,000	$ 0	$ 3,270,000	$ 0
Defined benefit plan contributions by employer		10,050,000	5,473,000	23,610,000	16,423,000
Pension Plan | CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Special/contractual termination benefits				2,400,000
Pension Plan | Support Group
Defined Benefit Plan Disclosure [Line Items]
Special/contractual termination benefits				900,000
Pension Plan | Other Subsidiaries
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan contributions by employer		1,800,000	900,000	3,600,000	2,600,000
Other Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Special/contractual termination benefits		0	0	0	0
Defined benefit plan contributions by employer		1,319,000	1,380,000	3,924,000	3,895,000
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	1,100,000	3,600,000	3,600,000
SERP
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan contributions by employer		946,000	1,575,000	2,837,000	4,726,000
SERP | CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan contributions by employer		$ 100,000	$ 200,000	$ 400,000	$ 700,000

Pension Plan and Employee Ben_4

Pension Plan and Employee Benefits - Net Periodic Pension and Benefits Cost (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
PENSION BENEFITS
Components of periodic benefit costs
Service cost	$ 2,629	$ 2,455	$ 7,887	$ 7,365
Interest cost	4,667	5,204	14,001	15,612
Expected return on plan assets	(5,700)	(6,244)	(17,101)	(18,731)
Amortizations
Prior period service credit	0	(15)	0	(45)
Net loss	5,184	4,073	15,553	12,222
Net periodic benefit cost	6,780	5,473	20,340	16,423
Special/contractual termination benefits	3,270	0	3,270	0
Total benefit cost	10,050	5,473	23,610	16,423
OTHER BENEFITS
Components of periodic benefit costs
Service cost	629	600	1,819	1,615
Interest cost	317	418	962	1,238
Expected return on plan assets	0	0	0	0
Amortizations
Prior period service credit	0	0	0	0
Net loss	373	362	1,143	1,042
Net periodic benefit cost	1,319	1,380	3,924	3,895
Special/contractual termination benefits	0	0	0	0
Total benefit cost	1,319	1,380	3,924	3,895
SERP
Components of periodic benefit costs
Service cost	59	100	174	300
Interest cost	634	733	1,903	2,199
Amortizations
Prior period service credit	(54)	(54)	(161)	(161)
Net loss	307	796	921	2,388
Total benefit cost	$ 946	$ 1,575	$ 2,837	$ 4,726

Pension Plan and Employee Ben_5

Pension Plan and Employee Benefits - Current and Non-Current Portions of the Other Benefits Liability (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Non-current	$ 320,504	$ 314,653
CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Non-current	237,818	230,825
Other Benefits Plan
Defined Benefit Plan Disclosure [Line Items]
Current	4,463	4,463
Non-current	51,306	51,868
Other Benefits Plan | CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Current	3,865	3,865
Non-current	$ 40,261	$ 40,734

Pension Plan and Employee Ben_6

Pension Plan and Employee Benefits - Current and Non-Current Portions of SERP Liability (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Defined Benefit Plan Disclosure [Line Items]
Non-current	$ 320,504	$ 314,653
SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Current	4,703	4,703
Non-current	90,880	92,522
CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Non-current	237,818	230,825
CLECO POWER | SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Current	711	711
Non-current	$ 19,240	$ 19,828

Pension Plan and Employee Ben_7

Pension Plan and Employee Benefits - 401 (K) Plans (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense		$ 2,512	$ 2,356	$ 7,391	$ 7,509
Percent of employees' gross pay, one time benefit (up to)	30.00%	30.00%		30.00%
401(k) Plan expense, additional cost	$ 200
Other Subsidiaries
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense		$ 1,185	$ 996	$ 3,511	$ 3,491

Income Taxes - Effective Tax Ra

Income Taxes - Effective Tax Rate Reconciliation (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Effective Income Tax Rate [Line Items]
Effective tax rate	20.30%	29.40%	12.40%	26.80%
CLECO POWER
Effective Income Tax Rate [Line Items]
Effective tax rate	1.00%	33.40%	(0.20%)	28.80%

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 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
Deferred employer payroll tax payments to be paid in 2021					3,000,000
Deferred employer payroll tax payments to be paid in 2022					3,000,000
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

Disclosures about Segments (Det

Disclosures about Segments (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020	Apr. 13, 2016
Revenue
Electric operations	$ 462,164	$ 386,388	$ 1,180,345	$ 1,019,501
Other operations	55,721	47,597	150,777	137,407
Affiliate revenue	0	0	0	0
Electric customer credits	(691)	(16,534)	(40,185)	(34,126)
Operating revenue, net	517,194	417,451	1,290,937	1,122,782
Net income	119,910	60,297	219,059	109,793
Depreciation and amortization	64,338	56,109	180,199	172,502
Interest income	941	910	2,416	2,964
Interest charges	34,629	34,060	101,812	103,923
Federal and state income tax expense	30,569	25,075	30,985	40,230
Other corporate costs and noncash items	71	(1,078)	(4,259)	6,807
EBITDA	248,576	173,553	525,380	430,291
Additions to property, plant, and equipment			209,960	215,692
Equity investment in investees	3,822		3,822		$ 9,072
Goodwill	1,490,797		1,490,797		1,490,797	$ 1,490,000
Total assets	8,395,807		8,395,807		7,725,569
CLECO POWER
Revenue
Electric operations	357,084	288,852	887,191	752,925
Other operations	22,779	17,775	57,674	49,443
Affiliate revenue	1,380	1,506	4,259	3,852
Electric customer credits	(691)	(16,534)	(40,429)	(33,974)
Operating revenue, net	380,552	291,599	908,695	772,246
Net income	56,561	36,092	102,407	76,156
Interest income	936	789	2,404	2,498
Interest charges	18,509	18,441	55,392	55,624
Federal and state income tax expense	548	18,076	(219)	30,770
Additions to property, plant, and equipment			202,940	205,765
Equity investment in investees	3,822		3,822		9,072
Total assets	5,256,041		5,256,041		4,766,147
Power supply agreements
Revenue
Amortization of intangible assets	6,400	6,400	19,200	19,200
OPERATING SEGMENTS
Revenue
Electric operations	464,584	388,808	1,187,606	1,026,761
Other operations	57,937	49,106	156,525	142,371
Affiliate revenue	1,380	1,506	4,259	4,056
Electric customer credits	(691)	(16,534)	(40,185)	(34,127)
Operating revenue, net	523,210	422,886	1,308,205	1,139,061
Net income	143,305	74,449	256,126	160,811
Depreciation and amortization	56,149	51,612	163,148	158,926
Interest income	940	799	2,414	2,767
Interest charges	19,626	17,957	56,178	55,271
Federal and state income tax expense	30,436	30,334	52,342	58,050
EBITDA	248,576	173,553	525,380	430,291
Additions to property, plant, and equipment			208,844	213,673
Equity investment in investees	3,822		3,822		9,072
Goodwill	1,490,797		1,490,797		1,490,797
Total assets	7,959,806		7,959,806		7,286,756
OPERATING SEGMENTS | CLECO POWER
Revenue
Electric operations	357,084	288,852	887,191	752,925
Other operations	22,779	17,775	57,674	49,443
Affiliate revenue	1,380	1,506	4,259	3,852
Electric customer credits	(691)	(16,534)	(40,429)	(33,974)
Operating revenue, net	380,552	291,599	908,695	772,246
Net income	56,561	36,092	102,407	76,156
Depreciation and amortization	43,526	40,268	126,534	125,541
Interest income	936	789	2,404	2,498
Interest charges	18,509	18,441	55,392	55,624
Federal and state income tax expense	548	18,076	(219)	30,770
EBITDA	118,208	112,088	281,710	285,593
Additions to property, plant, and equipment			202,940	205,765
Equity investment in investees	3,822		3,822		9,072
Goodwill	1,490,797		1,490,797		1,490,797
Total assets	6,746,838		6,746,838		6,256,944
OPERATING SEGMENTS | CLECO CAJUN
Revenue
Electric operations	107,500	99,956	300,415	273,836
Other operations	35,158	31,331	98,851	92,928
Affiliate revenue	0	0	0	204
Electric customer credits	0	0	244	(153)
Operating revenue, net	142,658	131,287	399,510	366,815
Net income	86,744	38,357	153,719	84,655
Depreciation and amortization	12,623	11,344	36,614	33,385
Interest income	4	10	10	269
Interest charges	1,117	(484)	786	(353)
Federal and state income tax expense	29,888	12,258	52,561	27,280
EBITDA	130,368	61,465	243,670	144,698
Additions to property, plant, and equipment			5,904	7,908
Equity investment in investees	0		0		0
Goodwill	0		0		0
Total assets	1,212,968		1,212,968		1,029,812
Amortization of deferred lease income	(2,300)	(2,300)	(6,900)	(6,900)
OPERATING SEGMENTS | CLECO CAJUN | Power supply agreements
Revenue
Amortization of intangible assets and liabilities	3,600	3,100	10,000	9,300
OTHER
Revenue
Electric operations	(2,420)	(2,420)	(7,260)	(7,260)
Other operations	1	1	4	2
Affiliate revenue	32,116	35,522	85,392	93,938
Electric customer credits	0	0	0	0
Operating revenue, net	29,697	33,103	78,136	86,680
Net income	(23,396)	(14,154)	(37,068)	(51,019)
Depreciation and amortization	8,189	4,497	17,052	13,575
Interest income	43	121	100	276
Interest charges	15,044	16,115	45,732	48,731
Federal and state income tax expense	133	(5,260)	(21,357)	(17,821)
Additions to property, plant, and equipment			1,116	2,019
Equity investment in investees	19,099		19,099		0
Goodwill	0		0		0
Total assets	685,410		685,410		595,217
OTHER | Power supply agreements | CLECO POWER
Revenue
Amortization of intangible assets	2,400	2,400	7,300	7,300
ELIMINATIONS
Revenue
Electric operations	0	0	(1)	0
Other operations	(2,217)	(1,510)	(5,752)	(4,966)
Affiliate revenue	(33,496)	(37,028)	(89,651)	(97,994)
Electric customer credits	0	0	0	1
Operating revenue, net	(35,713)	(38,538)	(95,404)	(102,959)
Net income	1	2	1	1
Depreciation and amortization	0	0	(1)	1
Interest income	(42)	(10)	(98)	(79)
Interest charges	(41)	(12)	(98)	(79)
Federal and state income tax expense	0	$ 1	0	1
Additions to property, plant, and equipment			0	$ 0
Equity investment in investees	(19,099)		(19,099)		0
Goodwill	0		0		0
Total assets	$ (249,409)		$ (249,409)		$ (156,404)

Regulation and Rates - Provisio

Regulation and Rates - Provision for Rate Refund (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020	Jun. 30, 2020	Jul. 31, 2019
Regulation and Rates [Line Items]
Provision for rate refund	$ 5,465	$ 9,444
Cleco Katrina/Rita storm recovery charges
Regulation and Rates [Line Items]
Provision for rate refund	1,610	1,617
FERC audit
Regulation and Rates [Line Items]
Provision for rate refund	0	1,912
FRP
Regulation and Rates [Line Items]
Provision for rate refund	1,236	1,786
Site-specific industrial customer
Regulation and Rates [Line Items]
Provision for rate refund	611	710
TCJA
Regulation and Rates [Line Items]
Provision for rate refund	2,057	2,057
Transmission ROE
Regulation and Rates [Line Items]
Provision for rate refund	0	595
CLECO POWER
Regulation and Rates [Line Items]
Provision for rate refund	5,465	8,630		$ 79,200
CLECO POWER | Cleco Katrina/Rita storm recovery charges
Regulation and Rates [Line Items]
Provision for rate refund	1,610	1,617
CLECO POWER | FERC audit
Regulation and Rates [Line Items]
Provision for rate refund	0	1,912
CLECO POWER | FRP
Regulation and Rates [Line Items]
Provision for rate refund	1,236	1,786	$ 1,200
CLECO POWER | Site-specific industrial customer
Regulation and Rates [Line Items]
Provision for rate refund	611	710
CLECO POWER | TCJA
Regulation and Rates [Line Items]
Provision for rate refund	2,057	2,057
CLECO POWER | Transmission ROE
Regulation and Rates [Line Items]
Provision for rate refund	$ 0	$ 595

Regulation and Rates - Narrativ

Regulation and Rates - Narrative (Details) $ in Thousands	Jun. 16, 2021	Sep. 30, 2021USD ($)complaint	Sep. 30, 2020USD ($)	Jun. 30, 2021	Sep. 30, 2021USD ($)complaint	Sep. 30, 2020USD ($)	Jul. 01, 2021USD ($)	Dec. 31, 2020USD ($)	Nov. 13, 2020USD ($)	Jun. 30, 2020USD ($)	Jul. 31, 2019USD ($)
Regulation and Rates [Line Items]
Refund due to customers		$ 5,465			$ 5,465			$ 9,444
Electric customer credits		691	$ 16,534		40,185	$ 34,126
Current regulatory liabilities		46,003			46,003			23,509
FRP
Regulation and Rates [Line Items]
Refund due to customers		1,236			1,236			1,786
Cleco Katrina/Rita storm recovery charges
Regulation and Rates [Line Items]
Refund due to customers		$ 1,610			$ 1,610			1,617
FERC
Regulation and Rates [Line Items]
Number of complaints filed | complaint		2			2
CLECO POWER
Regulation and Rates [Line Items]
Refund due to customers		$ 5,465			$ 5,465			8,630			$ 79,200
Electric customer credits		691	$ 16,534		40,429	$ 33,974
Regulatory liabilities		145,364			145,364			180,565
Current regulatory liabilities		46,003			46,003			23,509
CLECO POWER | FRP
Regulation and Rates [Line Items]
Refund due to customers		1,236			1,236			1,786		$ 1,200
CLECO POWER | Cleco Katrina/Rita storm recovery charges
Regulation and Rates [Line Items]
Refund due to customers		1,610			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			2,100
CLECO POWER | LPSC | Merger Commitments, cost savings
Regulation and Rates [Line Items]
Regulatory liabilities		$ 4,300			4,300
CLECO POWER | LPSC | FRP
Regulation and Rates [Line Items]
Target ROE allowed by FRP		9.50%		10.00%
Percentage of retail earnings within range to be returned to customers		60.00%		60.00%
ROE for customer credit, low range		10.00%		10.90%
ROE for customer credit, high range		10.50%		11.75%
CLECO POWER | LPSC | FRP | Maximum
Regulation and Rates [Line Items]
Target ROE allowed by FRP		10.00%		10.90%
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		$ 313,900			313,900
Current regulatory liabilities		$ 39,500			39,500
CLECO POWER | FERC
Regulation and Rates [Line Items]
Electric customer credits					$ 4,400

Variable Interest Entities - Na

Variable Interest Entities - Narrative (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Equity investment in investee	$ 3,822	$ 9,072
CLECO POWER
Variable Interest Entity [Line Items]
Equity investment in investee	3,822	$ 9,072
Equity investment, total return of capital	5,300
CLECO POWER | Oxbow | Oxbow
Variable Interest Entity [Line Items]
Costs to be billed	$ 1,800
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%

Variable Interest Entities - Eq

Variable Interest Entities - Equity Method Investments (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Total equity investment in investee	$ 3,822		$ 3,822		$ 9,072
Operating revenue, net	517,194	$ 417,451	1,290,937	$ 1,122,782
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	(15,450)		(15,450)		(10,200)
Total equity investment in investee	3,822		3,822		$ 9,072
Operating revenue, net	380,552	291,599	908,695	772,246
CLECO POWER | Equity Method Investment, Nonconsolidated Investee or Group of Investees
Schedule of Equity Method Investments [Line Items]
Operating revenue, net	1,486	2,275	5,113	33,266
Operating expenses	1,486	2,275	5,113	33,266
Income before taxes	$ 0	$ 0	$ 0	$ 0

Variable Interest Entities - Ca

Variable Interest Entities - Carrying Amount of Assets and Liabilities with Maximum Exposure to Loss (Details) - CLECO POWER - Oxbow - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Dec. 31, 2020
Variable Interest Entity [Line Items]
Oxbow’s net assets/liabilities	$ 7,645	$ 18,145
Cleco Power’s 50% equity	3,822	9,072
Cleco Power’s maximum exposure to loss	$ 3,822	$ 9,072
Ownership percentage by Cleco Power	50.00%

Litigation, Other Commitments_3

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation (Details) $ in Thousands

Oct. 20, 2021USD ($)

Jun. 01, 2020

May 21, 2020

Jan. 01, 2020

Sep. 30, 2016

Jun. 30, 2016

Sep. 30, 2015USD ($)

Dec. 31, 2014claim

Nov. 30, 2014claim

Sep. 30, 2021USD ($)

Sep. 30, 2020USD ($)

Sep. 30, 2021USD ($)

Sep. 30, 2020USD ($)

Dec. 31, 2019USD ($)

May 31, 2016

Mar. 29, 2021USD ($)

Sep. 27, 2019recommendationfinding

Loss Contingencies [Line Items]

Electric customer credits

$ 691

$ 16,534

$ 40,185

$ 34,126

Loss contingency, estimate of possible loss

4,100

4,100

South Central Generating

Loss Contingencies [Line Items]

Loss contingency, estimate of possible loss

1,500

1,500

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

691

$ 16,534

40,429

$ 33,974

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 | Subsequent event

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

CLECO POWER | FERC | MISO Transmission Rates

Loss Contingencies [Line Items]

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%

Litigation, Other Commitments_4

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Off-Balance Sheet Commitments and Guarantees (Details) - USD ($)	1 Months Ended	9 Months Ended
	Mar. 31, 2021	Sep. 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
Indemnification Agreement including fundamental organizational structure
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted		400,000,000
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
CLECO POWER | Indemnification Agreement including fundamental organizational structure
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted		$ 400,000,000
Cleco Cajun | Letters of Credit | Deferred storm restoration costs - Winter Storms Uri & Viola
Guarantor Obligations [Line Items]
Collateral returned	$ 6,500,000

Litigation, Other Commitments_5

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Asset Retirement Obligation (Details) $ in Thousands	3 Months Ended	9 Months Ended
	Sep. 30, 2021USD ($)	Sep. 30, 2021USD ($)
Loss Contingencies [Line Items]
Revisions and adjustments		$ 48,641
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance		28,022
Liabilities settled		(1,316)
Accretion		715
Revisions and adjustments		48,641
Ending balance	$ 76,062	76,062
CLECO POWER
Loss Contingencies [Line Items]
Revisions and adjustments	13,100	13,101
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance		11,364
Liabilities settled		0
Accretion		249
Revisions and adjustments	13,100	13,101
Ending balance	24,714	24,714
Cleco Cajun
Loss Contingencies [Line Items]
Revisions and adjustments	35,500	35,540
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance		16,658
Liabilities settled		(1,316)
Accretion		466
Revisions and adjustments	35,500	35,540
Ending balance	51,348	51,348
Indemnification assets, maximum environmental costs	25,000	25,000
Indemnification assets	22,100	22,100
Indemnification assets, current	1,100	1,100
Indemnification assets, noncurrent	$ 21,000	$ 21,000

Litigation, Other Commitments_6

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Risks and Uncertainties (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	9 Months Ended
	Jun. 30, 2020	Sep. 30, 2021	Sep. 30, 2021
Loss Contingencies [Line Items]
Revisions and adjustments			$ 48,641
CLECO POWER
Loss Contingencies [Line Items]
Revisions and adjustments		$ 13,100	13,101
CLECO POWER | Dolet Hills Power Station
Loss Contingencies [Line Items]
Revisions and adjustments	$ 3,300
Investment balance		38,600	38,600
CLECO POWER | Dolet Hills Power Station | DHLC
Loss Contingencies [Line Items]
Costs to be billed		10,100	10,100
CLECO POWER | Oxbow | Oxbow
Loss Contingencies [Line Items]
Costs to be billed		$ 1,800	$ 1,800

Affiliate Transactions - Narrat

Affiliate Transactions - Narrative (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Related Party Transaction [Line Items]
Accounts receivable - affiliate	$ 3,038		$ 3,038		$ 1,663
Accounts payable - affiliate	41,283		41,283		41,283
CLECO POWER
Related Party Transaction [Line Items]
Accounts receivable - affiliate	13,982		13,982		14,605
Accounts payable - affiliate	69,356		69,356		72,068
CLECO POWER | Cleco Holdings
Related Party Transaction [Line Items]
Accounts receivable - affiliate	10,712		10,712		10,353
Accounts payable - affiliate	57,825		57,825		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	2,388		2,388		3,248
Accounts payable - affiliate	11,514		11,514		14,355
CLECO POWER | Oxbow | Affiliates
Related Party Transaction [Line Items]
Cost of mineral rights and land leases	700	$ 1,100	2,700	$ 16,600
Due to affiliates	$ 200		$ 200		$ 300

Affiliate Transactions - Summar

Affiliate Transactions - Summary of Balances Payable To or Due From Affiliates (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	$ 3,038	$ 1,663
ACCOUNTS PAYABLE	41,283	41,283
CLECO POWER
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	13,982	14,605
ACCOUNTS PAYABLE	69,356	72,068
CLECO POWER | Cleco Holdings
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	10,712	10,353
ACCOUNTS PAYABLE	57,825	57,713
CLECO POWER | Support Group
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	2,388	3,248
ACCOUNTS PAYABLE	11,514	14,355
CLECO POWER | Cleco Cajun
Related Party Transaction [Line Items]
ACCOUNTS RECEIVABLE	882	1,004
ACCOUNTS PAYABLE	$ 17	$ 0

Intangible Assets and Liabili_3

Intangible Assets and Liabilities - Narrative (Details) - USD ($)	Aug. 01, 2021	Sep. 30, 2021	Dec. 31, 2008	Dec. 31, 2020	Mar. 31, 2020	Apr. 13, 2016
Finite-Lived Intangible Assets [Line Items]
Intangible assets		$ 88,635,000		$ 111,731,000
Goodwill		1,490,797,000		$ 1,490,797,000		$ 1,490,000,000
Goodwill impairment	$ 0
Trade name
Finite-Lived Intangible Assets [Line Items]
Intangible assets, residual value		0
Impairment of intangible assets		3,800,000
Intangible assets		$ 0
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
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		6 years
Cleco Cajun | Power supply agreements | Maximum
Finite-Lived Intangible Assets [Line Items]
Intangible assets, remaining life		8 years

Intangible Assets and Liabili_4

Intangible Assets and Liabilities - Schedule of Amortization of Intangible Assets and Liabilities (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
LTSA
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible liabilities	$ 871	$ 871	$ 2,613	$ 2,613
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible liabilities	389	882	1,989	2,646
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	3,770	64	3,897	191
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 6,400	$ 6,400	$ 19,200	$ 19,200

Intangible Assets and Liabili_5

Intangible Assets and Liabilities - Schedule of Finite-Lived Intangible Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Finite-Lived Intangible Assets [Line Items]
Total intangible assets carrying amount	$ 184,004	$ 189,104
Total intangible liability carrying amount	38,300	38,300
Net intangible assets carrying amount	145,704	150,804
Accumulated amortization	(77,326)	(63,932)
Net intangible assets subject to amortization	68,378	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	0	5,100
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Total intangible assets carrying amount	$ 184,004	$ 184,004

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	$ 2,856,380	$ 2,693,358	$ 2,757,023	$ 2,643,006
Balances, end of period	2,976,386	2,754,103	2,976,386	2,754,103
TOTAL AOCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(25,588)	(16,657)	(25,796)	(17,513)
Balances, end of period	(25,492)	(16,209)	(25,492)	(16,209)
POSTRETIREMENT BENEFIT NET LOSS
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(25,588)	(16,657)	(25,796)	(17,513)
Amounts reclassified from AOCI	96	448	304	1,304
Balances, end of period	(25,492)	(16,209)	(25,492)	(16,209)
CLECO POWER
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	1,854,598	1,754,429	1,807,879	1,713,392
Balances, end of period	1,911,572	1,790,957	1,911,572	1,790,957
CLECO POWER | TOTAL AOCI
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(23,880)	(21,612)	(24,753)	(22,585)
Balances, end of period	(23,467)	(21,176)	(23,467)	(21,176)
CLECO POWER | POSTRETIREMENT BENEFIT NET LOSS
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(18,394)	(15,872)	(19,139)	(16,717)
Amounts reclassified from AOCI	350	373	1,095	1,218
Balances, end of period	(18,044)	(15,499)	(18,044)	(15,499)
CLECO POWER | NET LOSS ON CASH FLOW HEDGES
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Balances, beginning of period	(5,486)	(5,740)	(5,614)	(5,868)
Amounts reclassified from AOCI	63	63	191	191
Balances, end of period	$ (5,423)	$ (5,677)	$ (5,423)	$ (5,677)

Storm Restoration (Details)

Storm Restoration (Details) customer in Thousands, $ in Thousands

May 19, 2021USD ($)

May 31, 2021

Mar. 31, 2021USD ($)

Oct. 28, 2020USD ($)hurricane

Sep. 30, 2021USD ($)

Sep. 28, 2021USD ($)

Sep. 11, 2021

Aug. 29, 2021customer

Aug. 05, 2021USD ($)

Mar. 29, 2021USD ($)

Feb. 17, 2021customer

Feb. 14, 2021customer

Dec. 31, 2020USD ($)

Unusual or Infrequent Item, or Both [Line Items]

Securitized storm restoration costs

$ 342,000

Securitized storm restoration costs, reserve for future costs

$ 100,000

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%

Deferred storm restoration costs - Hurricane Ida

Unusual or Infrequent Item, or Both [Line Items]

Securitized storm restoration costs, reserve for future costs

$ 100,000

CLECO POWER

Unusual or Infrequent Item, or Both [Line Items]

Regulatory assets

$ 721,426

$ 456,034

CLECO POWER | Hurricane Laura, Delta and Zeta

Unusual or Infrequent Item, or Both [Line Items]

Regulatory assets

78,200

CLECO POWER | Deferred storm restoration costs - Winter Storms Uri & Viola

Unusual or Infrequent Item, or Both [Line Items]

Regulatory assets

1,974

0

CLECO POWER | Deferred storm restoration costs - Hurricane Ida

Unusual or Infrequent Item, or Both [Line Items]

Regulatory assets

36,836

$ 0

CLECO POWER | Hurricanes

Unusual or Infrequent Item, or Both [Line Items]

Number of hurricanes | hurricane

3

Estimate of storm restoration costs

$ 242,600

Capitalized storm restoration costs

$ 152,200

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

8,400

$ 50,000

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 POWER | Winter Storm Uri

Unusual or Infrequent Item, or Both [Line Items]

Number of customers affected with power outage | customer

11

CLECO POWER | Winter Storm Viola

Unusual or Infrequent Item, or Both [Line Items]

Number of customers affected with power outage | customer

43

CLECO POWER | Deferred storm restoration costs - Hurricane Ida

Unusual or Infrequent Item, or Both [Line Items]

Capitalization percentage

56.00%

Capitalized storm restoration costs

$ 49,100

Number of customers affected with power outage | customer

100

Percentage of customers affected by the hurricane with power restored

100.00%

CLECO POWER | Deferred storm restoration costs - Hurricane Ida | Minimum

Unusual or Infrequent Item, or Both [Line Items]

Estimate of storm restoration costs

85,000

CLECO POWER | Deferred storm restoration costs - Hurricane Ida | Maximum

Unusual or Infrequent Item, or Both [Line Items]

Estimate of storm restoration costs

$ 95,000

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