Cleco Corporate 10-Q 2 May 18 2018 Q1 Quarterly report Financial data

Document And Entity Information

Document And Entity Information - shares	3 Months Ended
	Mar. 31, 2018	May 02, 2018
Entity Information [Line Items]
Entity Registrant Name	Cleco Corporate Holdings LLC
Entity Central Index Key	1,089,819
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Mar. 31, 2018
Document Fiscal Year Focus	2,018
Document Fiscal Period Focus	Q1
Amendment Flag	false
Entity Common Stock, Shares Outstanding (in shares)		0
Cleco Power
Entity Information [Line Items]
Entity Registrant Name	CLECO POWER LLC
Entity Central Index Key	18,672
Entity Filer Category	Non-accelerated Filer

Condensed Consolidated Statemen

Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Operating revenue
Electric operations	$ 262,211	$ 234,056
Other operations	22,196	16,880
Affiliate revenue	0	0
Gross operating revenue	284,407	250,936
Electric customer credits	(7,647)	(435)
Operating revenue, net	276,760	250,501
Operating expenses
Fuel used for electric generation	67,016	69,873
Power purchased for utility customers	53,159	31,963
Other operations	27,967	29,327
Maintenance	29,119	24,523
Depreciation and amortization	42,507	40,851
Taxes other than income taxes	12,258	12,502
Total operating expenses	232,026	209,039
Operating income	44,734	41,462
Interest income	783	312
Allowance for equity funds used during construction	2,363	911
Other income	554	1,370
Other expense	(3,554)	(2,938)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	32,030	31,945
Allowance for borrowed funds used during construction	(873)	(227)
Total interest charges	31,157	31,718
Income before income taxes	13,723	9,399
Federal and state income tax expense	2,862	3,107
Net income	10,861	6,292
Cleco Power
Operating revenue
Electric operations	264,631	237,553
Other operations	22,195	16,365
Affiliate revenue	208	219
Gross operating revenue	287,034	254,137
Electric customer credits	(7,647)	(435)
Operating revenue, net	279,387	253,702
Operating expenses
Fuel used for electric generation	67,016	69,873
Power purchased for utility customers	53,159	31,963
Other operations	27,307	30,264
Maintenance	29,078	24,420
Depreciation and amortization	40,388	38,758
Taxes other than income taxes	11,918	12,000
Total operating expenses	228,866	207,278
Operating income	50,521	46,424
Interest income	641	266
Allowance for equity funds used during construction	2,363	911
Other income	740	210
Other expense	(2,608)	(1,998)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	18,529	18,331
Allowance for borrowed funds used during construction	(873)	(227)
Total interest charges	17,656	18,104
Income before income taxes	34,001	27,709
Federal and state income tax expense	7,997	9,855
Net income	$ 26,004	$ 17,854

Condensed Consolidated Stateme3

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Net income	$ 10,861	$ 6,292
Other comprehensive income (loss), net of tax
Postretirement benefits (loss) gain, net of tax	43	(2,191)
Total other comprehensive income (loss), net of tax	43	(2,191)
Comprehensive income, net of tax	10,904	4,101
Cleco Power
Net income	26,004	17,854
Other comprehensive income (loss), net of tax
Postretirement benefits (loss) gain, net of tax	233	(420)
Amortization of interest rate derivatives to earnings, net of tax	64	53
Total other comprehensive income (loss), net of tax	297	(367)
Comprehensive income, net of tax	$ 26,301	$ 17,487

Condensed Consolidated Stateme4

Condensed Consolidated Statements of Comprehensive Income (Unaudited) (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Net tax expense (benefit) of gain (loss) on postretirement benefits	$ 15	$ (1,370)
Cleco Power
Net tax expense (benefit) of gain (loss) on postretirement benefits	83	(262)
Net tax expense on cash flow hedges	$ 22	$ 33

Condensed Consolidated Balance

Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Current assets
Cash and cash equivalents	$ 176,508	$ 119,040
Restricted cash and cash equivalents	6,727	13,081
Customer accounts receivable (less allowance for doubtful accounts)	52,277	60,117
Other accounts receivable	22,680	30,806
Unbilled revenue	30,011	36,398
Fuel inventory, at average cost	73,215	87,520
Materials and supplies, at average cost	88,420	85,404
Energy risk management assets	4,828	7,396
Accumulated deferred fuel	23,053	13,980
Cash surrender value of company-/trust-owned life insurance policies	82,771	83,117
Prepayments	6,690	9,050
Regulatory assets	22,207	24,670
Other current assets	681	1,146
Total current assets	590,068	571,725
Property, plant, and equipment
Property, plant, and equipment	3,629,249	3,594,525
Accumulated depreciation	(221,941)	(192,348)
Net property, plant, and equipment	3,407,308	3,402,177
Construction work in progress	212,847	186,629
Total property, plant, and equipment, net	3,620,155	3,588,806
Equity investment in investee	18,172	18,172
Goodwill	1,490,797	1,490,797
Restricted cash and cash equivalents	19,327	20,081
Regulatory assets	425,041	432,358
Intangible assets	107,881	114,850
Other deferred charges	38,540	41,593
Total assets	6,309,981	6,278,382
Current liabilities
Long-term debt due within one year	19,875	19,193
Accounts payable	95,542	147,562
Customer deposits	59,765	58,582
Provision for rate refund	11,805	4,206
Taxes payable, net	34,264	22,698
Interest accrued	40,924	14,703
Deferred compensation	11,322	12,132
Other current liabilities	21,633	21,278
Total current liabilities	295,130	300,354
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	618,657	614,812
Postretirement benefit obligations	243,084	242,135
Regulatory liabilities - deferred taxes, net	138,329	140,426
Restricted storm reserve	14,705	14,469
Other deferred credits	38,251	33,724
Total long-term liabilities and deferred credits	1,053,026	1,045,566
Long-term debt, net	2,874,064	2,836,105
Total liabilities	4,222,220	4,182,025
Commitments and contingencies (Note 12)
Member’s equity
Membership interest	2,069,376	2,069,376
Retained earnings	21,263	29,902
Accumulated other comprehensive loss	(2,878)	(2,921)
Total member’s equity	2,087,761	2,096,357
Total liabilities and member’s equity	6,309,981	6,278,382
Cleco Power
Current assets
Cash and cash equivalents	128,182	69,816
Restricted cash and cash equivalents	6,727	13,081
Customer accounts receivable (less allowance for doubtful accounts)	52,277	60,117
Accounts receivable - affiliate	1,311	1,355
Other accounts receivable	22,278	30,680
Unbilled revenue	30,011	36,398
Fuel inventory, at average cost	73,215	87,520
Materials and supplies, at average cost	88,420	85,404
Energy risk management assets	4,828	7,396
Accumulated deferred fuel	23,053	13,980
Cash surrender value of company-/trust-owned life insurance policies	20,341	20,278
Prepayments	5,000	7,236
Regulatory assets	13,350	15,812
Other current assets	0	475
Total current assets	468,993	449,548
Property, plant, and equipment
Property, plant, and equipment	4,924,970	4,893,484
Accumulated depreciation	(1,737,911)	(1,712,590)
Net property, plant, and equipment	3,187,059	3,180,894
Construction work in progress	212,727	185,507
Total property, plant, and equipment, net	3,399,786	3,366,401
Equity investment in investee	18,172	18,172
Restricted cash and cash equivalents	19,306	20,060
Regulatory assets	252,889	257,408
Intangible assets	37,216	41,701
Other deferred charges	35,125	35,451
Total assets	4,231,487	4,188,741
Current liabilities
Long-term debt due within one year	19,875	19,193
Accounts payable	87,607	134,374
Accounts payable - affiliate	9,969	8,697
Customer deposits	59,765	58,582
Provision for rate refund	11,805	4,206
Taxes payable, net	45,197	31,611
Interest accrued	22,638	7,083
Other current liabilities	16,960	16,172
Total current liabilities	273,816	279,918
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	663,255	656,362
Postretirement benefit obligations	174,971	173,747
Regulatory liabilities - deferred taxes, net	138,329	140,426
Restricted storm reserve	14,705	14,469
Other deferred credits	36,022	31,665
Total long-term liabilities and deferred credits	1,027,282	1,016,669
Long-term debt, net	1,381,409	1,341,475
Total capitalization	2,930,389	2,892,154
Commitments and contingencies (Note 12)
Member’s equity
Total member’s equity	1,548,980	1,550,679
Total liabilities and member’s equity	$ 4,231,487	$ 4,188,741

Condensed Consolidated Balance6

Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Current assets
Customer accounts receivable, allowance for doubtful accounts	$ 1,424	$ 1,457
Cleco Power
Current assets
Customer accounts receivable, allowance for doubtful accounts	$ 1,424	$ 1,457

Condensed Consolidated Stateme7

Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018		Mar. 31, 2017
Operating activities
Net income	$ 10,861		$ 6,292
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	46,754		46,727
Unearned compensation expense	1,116		955
Allowance for equity funds used during construction	(2,363)		(911)
Deferred income taxes	1,733		3,041
Deferred fuel costs	(11,353)		(2,982)
Cash surrender value of company-/trust-owned life insurance	346		(1,702)
Changes in assets and liabilities
Accounts receivable	10,563		8,346
Unbilled revenue	6,387		4,765
Fuel inventory and materials and supplies	11,573		(7,733)
Prepayments	2,199		1,318
Accounts payable	(40,239)		(27,148)
Customer deposits	3,500		2,622
Provision for merger commitments	(1,187)		(3,866)
Postretirement benefit obligations	1,007		1,213
Regulatory assets and liabilities, net	3,960		2,599
Other deferred accounts	5,871		1,920
Taxes accrued	11,108		12,568
Interest accrued	26,220		25,620
Other operating	(93)		1,138
Net cash provided by operating activities	87,963		74,782
Investing activities
Additions to property, plant, and equipment	(64,133)		(47,890)
Allowance for equity funds used during construction	2,363		911
Reimbursement for property loss	1,172		39
Return of equity investment in tax credit fund	2,775		426
Other investing	75		(388)
Net cash used in investing activities	(57,748)		(46,902)
Financing activities
Issuances of long-term debt	50,000		0
Repayment of long-term debt	(9,700)		(9,060)
Distributions to member	(19,500)		(28,955)
Other financing	(655)		(213)
Net cash provided by (used in) financing activities	20,145		(38,228)
Net increase (decrease) in cash, cash equivalents, restricted cash, and restricted cash equivalents	50,360		(10,348)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	152,202	[1]	69,571
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	202,562	[2]	59,223
Supplementary cash flow information
Interest paid, net of amount capitalized	4,236		4,011
Income taxes refunded, net	270		1
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	35,067		27,617
Cleco Power
Operating activities
Net income	26,004		17,854
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	42,022		40,871
Allowance for equity funds used during construction	(2,363)		(911)
Deferred income taxes	4,692		10,135
Deferred fuel costs	(11,353)		(2,982)
Changes in assets and liabilities
Accounts receivable	10,710		8,064
Unbilled revenue	6,387		4,765
Fuel inventory and materials and supplies	11,573		(7,733)
Prepayments	2,075		925
Accounts payable	(35,030)		(23,836)
Accounts payable, affiliate	672		2,083
Customer deposits	3,500		2,622
Provision for merger commitments	(1,187)		(3,866)
Postretirement benefit obligations	1,061		1,026
Regulatory assets and liabilities, net	3,463		2,103
Other deferred accounts	6,116		1,494
Taxes accrued	13,127		11,769
Interest accrued	15,555		14,230
Other operating	2,322		2,566
Net cash provided by operating activities	99,346		81,179
Investing activities
Additions to property, plant, and equipment	(63,343)		(46,744)
Allowance for equity funds used during construction	2,363		911
Reimbursement for property loss	1,172		39
Other investing	75		242
Net cash used in investing activities	(59,733)		(45,552)
Financing activities
Issuances of long-term debt	50,000		0
Repayment of long-term debt	(9,700)		(9,060)
Distributions to member	(28,000)		(35,000)
Other financing	(655)		(675)
Net cash provided by (used in) financing activities	11,645		(44,735)
Net increase (decrease) in cash, cash equivalents, restricted cash, and restricted cash equivalents	51,258		(9,108)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	102,957	[3]	67,955
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	154,215	[4]	58,847
Supplementary cash flow information
Interest paid, net of amount capitalized	1,789		2,212
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$ 35,038		$ 27,493
[1]	Includes cash and cash equivalents are $119,040, current restricted cash and cash equivalents are $13,081, non-current restricted cash and cash equivalents are $20,081.
[2]	Includes cash and cash equivalents are $176,508, current restricted cash and cash equivalents are $6,727, non-current restricted cash and cash equivalents are $19,327.
[3]	Includes cash and cash equivalents are $69,816, current restricted cash and cash equivalents are $13,081, non-current restricted cash and cash equivalents are $20,060.
[4]	Includes cash and cash equivalents are $128,182, current restricted cash and cash equivalents are $6,727, non-current restricted cash and cash equivalents are $19,306.

Condensed Consolidated Stateme8

Condensed Consolidated Statements of Cash Flows (Unaudited) - Parenthetical - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Cash and cash equivalents	$ 176,508	$ 119,040
Restricted cash and cash equivalents, current	6,727	13,081
Restricted cash and cash equivalents, noncurrent	19,327	20,081
Cleco Power
Cash and cash equivalents	128,182	69,816
Restricted cash and cash equivalents, current	6,727	13,081
Restricted cash and cash equivalents, noncurrent	$ 19,306	$ 20,060

Condensed Consolidated Stateme9

Condensed Consolidated Statement of Changes in Equity (Unaudited) - 3 months ended Mar. 31, 2018 - USD ($) $ in Thousands	Total	MEMBERSHIP INTEREST	RETAINED EARNINGS	AOCI	Cleco Power	Cleco PowerMEMBER’S EQUITY	Cleco PowerAOCI
Balances, beginning of period at Dec. 31, 2017	$ 2,096,357	$ 2,069,376	$ 29,902	$ (2,921)	$ 1,550,679	$ 1,564,362	$ (13,683)
Increase (Decrease) in Equity [Roll Forward]
Distributions to member	(19,500)		(19,500)		(28,000)	(28,000)
Net income	10,861		10,861		26,004	26,004
Other comprehensive income, net of tax	43			43	297		297
Balances, end of period at Mar. 31, 2018	$ 2,087,761	$ 2,069,376	$ 21,263	$ (2,878)	$ 1,548,980	$ 1,562,366	$ (13,386)

Summary of Significant Accounti

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2018
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 1 — Summary of Significant Accounting Policies Principles of Consolidation The accompanying Condensed Consolidated Financial Statements of Cleco include the accounts of Cleco Holdings 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 the 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 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 year ended December 31, 2017. These Condensed Consolidated Financial Statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly state the financial position and results of operations of Cleco and Cleco Power. Amounts reported in Cleco and Cleco Power’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, discrete income tax items, and other factors. In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates. For information on recent authoritative guidance and its effect on financial results, see Note 3 — “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: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current Cleco Katrina/Rita’s storm recovery bonds $ 2,601 $ 8,597 Cleco Power’s charitable contributions 1,200 1,200 Cleco Power’s rate credit escrow 2,926 3,284 Total current 6,727 13,081 Non-current Diversified Lands’ mitigation escrow 21 21 Cleco Power’s future storm restoration costs 14,705 14,456 Cleco Power’s charitable contributions 3,044 3,575 Cleco Power’s rate credit escrow 1,557 2,029 Total non-current 19,327 20,081 Total restricted cash and cash equivalents $ 26,054 $ 33,162 Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current Cleco Katrina/Rita’s storm recovery bonds $ 2,601 $ 8,597 Charitable contributions 1,200 1,200 Rate credit escrow 2,926 3,284 Total current 6,727 13,081 Non-current Future storm restoration costs 14,705 14,456 Charitable contributions 3,044 3,575 Rate credit escrow 1,557 2,029 Total non-current 19,306 20,060 Total restricted cash and cash equivalents $ 26,033 $ 33,141 Cleco Katrina/Rita has the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash is collected, it is restricted for payment of administration fees, interest, and principal on storm recovery bonds. The change from December 31, 2017 , to March 31, 2018 , was due to Cleco Katrina/Rita using $9.7 million for a scheduled storm recovery bond principal payment and $1.4 million for the related interest payment, partially offset by collections of $5.1 million net of administration fees. Fair Value Measurements and Disclosures Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes. For more information about fair value levels, see Note 5 — “Fair Value Accounting.” Risk Management Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes in value arising from changes in interest rates and the commodity market prices of power, FTRs, and natural gas in the industry on different energy exchanges. Cleco’s Energy Market Risk Management Policy authorizes the use of various derivative instruments, including exchange traded futures and option contracts, forward purchase and sales contracts, and swap transactions to reduce exposure to fluctuations in the price of power, FTRs, and natural gas. Cleco evaluates derivatives and hedging activities to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market. Cleco Power may also enter into risk mitigating positions that would not meet the requirements of a normal-purchase, normal-sale transaction in order to attempt to mitigate the volatility in customer fuel costs. These positions would be marked-to-market with the resulting gain or loss recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets as a component of energy risk management assets or liabilities. Such gain or loss would be deferred as a component of deferred fuel assets or liabilities in accordance with regulatory policy. When these positions close, actual gains or losses would be included in the FAC and reflected on customers’ bills as a component of the fuel charge. There were no open natural gas positions at March 31, 2018 , or December 31, 2017 . In 2015, the LPSC approved a long-term natural gas hedging pilot program that requires Cleco Power to establish a proposal for a program that will be designed to provide gas price stability for a minimum of five years. Cleco Power’s proposal was submitted to the LPSC in July 2017. An ALJ has been assigned to the docket and a status conference was held in October 2017. On February 28, 2018, Cleco Power responded to LPSC data requests for the gas hedging docket. Cleco Power is currently awaiting a new procedural schedule to be established. Cleco Power purchases FTRs in auctions facilitated by MISO. The majority of its FTRs are purchased in annual auctions during the second quarter, but Cleco Power may purchase additional FTRs in monthly auctions. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Cleco Power’s customer load. FTRs are not designated as hedging instruments for accounting purposes. Cleco Power records FTRs at their estimated fair value when purchased. Each accounting period, Cleco Power adjusts the carrying value of FTRs to their estimated fair value based on the most recent MISO FTR auction prices. Unrealized gains or losses on FTRs held by Cleco Power are included in Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheets. Realized gains or losses on settled FTRs are recorded in Fuel used for electric generation on Cleco Power’s Condensed Consolidated Statements of Income. For more information on FTRs, see Note 5 — “Fair Value Accounting — Commodity Contracts.” Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, aggregate counterparty credit exposure, and aggregate counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits, or letters of credit from counterparties or their affiliates, as deemed necessary. Cleco Power has agreements in place with various counterparties that authorize the netting of financial buys and sells and contract payments to mitigate credit risk for transactions entered into for risk management purposes. Cleco and Cleco Power may enter into contracts to mitigate the volatility in interest rate risk. These contracts include, but are not limited to, interest rate swaps and treasury rate locks. For the three months ended March 31, 2018, and March 31, 2017, Cleco did not enter into any contracts to mitigate the volatility in interest rate risk.

Revenue Recognition

Revenue Recognition	3 Months Ended
	Mar. 31, 2018
Revenue from Contract with Customer [Abstract]
Revenue Recognition	Note 2 — Revenue Recognition Cleco adopted the accounting guidance for revenue recognition and all related amendments on January 1, 2018, using the modified retrospective method. The guidance affects entities that enter into contracts for the transfer of nonfinancial assets unless those contracts are within the scope of other standards. The core principle of this guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. Application of the new revenue standard did not result in a cumulative effect adjustment to the opening balance of retained earnings. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The impact of the adoption of the new standard is not material to the results of operations, financial condition, or cash flows of the Registrants. Revenue from Contracts with Customers Retail Utility Revenue Cleco’s revenue from contracts with customers is generated primarily from Cleco Power’s regulated revenue to retail residential, commercial, and industrial customers. Cleco recognizes retail revenue from these contracts as a series, and progress towards satisfaction of the performance obligation is measured using an output method based on kWh delivered. Accordingly, revenue from electricity sales is recognized as energy is delivered to the customer. Cleco bills retail customers, based on rates regulated by the LPSC, on a monthly basis with payments generally due within 20 days of the invoice date. Cleco records retail revenue under the invoice practical expedient, which states that if an entity has a right to consideration from a customer in an amount that corresponds directly with the value to the customer of the entity’s performance completed to date, the entity may recognize revenue in the amount that the entity has a right to invoice. Included in Cleco’s retail revenue is unbilled electric revenue which represents the amount customers will be billed for services rendered from the last meter reading to the end of the respective accounting period. Cleco uses actual customer energy consumption data available from AMI to calculate unbilled revenue. Wholesale Revenue Wholesale revenue is generated primarily through the sale of energy and capacity to municipalities and the MISO transmission provider. Cleco also enters into transactions through MISO for spot energy sales which are transacted in the Day-Ahead Energy and Operating Reserves Market and the Real-Time Energy and Operating Reserves Market. The electricity revenue performance obligations, representing both energy and capacity, are satisfied as a series of performance obligations, and progress towards satisfaction of the performance obligations are measured using an output method. The energy performance obligation measure of progress is based on kWh delivered. The capacity performance obligation measure of progress is based on time elapsed and will be recognized each month as Cleco’s generating units stand ready to deliver electricity to the customer. Cleco charges its wholesale customers market based rates that are subject to FERC’s triennial market power analysis. Cleco recognizes wholesale revenue, inclusive of both performance obligations, under the invoice practical expedient for the amount Cleco has the right to invoice. Transmission Revenue Transmission revenue is earned under a tariff with MISO. The performance obligation of transmission service is satisfied as service is provided. Revenue is recognized upon delivery of the transmission service. Cleco’s revenue from the transmission of electricity is recorded based on a FERC-approved annual formula rate mechanism. This mechanism provides for an annual filing of an estimated revenue requirement with rates effective January 1 of each year and a mechanism to true-up that estimate based on actual revenue requirements. Other Revenue Other revenue from contracts with customers, which is not a significant source of Cleco’s revenue, includes Teche Unit 3 SSR revenue, connection or other fees, and electric customer credits. The performance obligation under these contracts is satisfied and revenue is recognized as control of the products is delivered or services are rendered. Revenue Unrelated to Contracts with Customers Certain energy-related transactions, where Cleco records the change in value of those contracts, qualify as derivative contracts and are recorded pursuant to derivatives and hedging accounting guidance. Disaggregated Revenue Operating revenue, net for the three months ended March 31, 2018, was as follows: FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 91,390 $ — $ — $ 91,390 Commercial (1) 66,695 — — 66,695 Industrial (1) 37,386 — — 37,386 Other retail (1) 3,801 — — 3,801 Surcharge 5,238 — — 5,238 Total retail revenue $ 204,510 $ — $ — $ 204,510 Wholesale, net (1) 43,830 (2,420 ) (2) — 41,410 Transmission 17,644 — — 17,644 Other (3) 43 1 — 44 Total revenue from contracts with customers $ 266,027 $ (2,419 ) $ — $ 263,608 Revenue unrelated to contracts with customers Affiliate $ 208 $ 15,669 $ (15,877 ) $ — Other 13,152 — — 13,152 Total revenue unrelated to contracts with customers 13,360 15,669 (15,877 ) 13,152 Operating revenue, net $ 279,387 $ 13,250 $ (15,877 ) $ 276,760 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to wholesale power supply agreements. (3) Other revenue from contracts with customers includes $3.2 million of Teche Unit 3 SSR revenue, net of $1.9 million of reserves for capital expenditures, and other miscellaneous fee revenue, partially offset by electric customer credits. Transaction Price Allocated to Remaining Performance Obligations For wholesale contracts that are greater than one year, the following table discloses (1) the aggregate amount of the transaction price allocated to performance obligations that are unsatisfied (or partially unsatisfied) as of March 31, 2018, and (2) when Cleco expects to recognize this revenue: REMAINING PERFORMANCE OBLIGATIONS (THOUSANDS) Nine months ending Dec. 31, 2018 $ 7,721 Years ending Dec. 31, 2019 6,779 2020 7,068 2021 7,068 2022 6,468 Thereafter 10,210 Total wholesale contracts $ 45,314 Unsatisfied performance obligations primarily relate to stand-ready obligations as part of fixed capacity minimums.

Recent Authoritative Guidance

Recent Authoritative Guidance	3 Months Ended
	Mar. 31, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Recent Authoritative Guidance	Note 3 — Recent Authoritative Guidance The Registrants adopted, or will adopt, the recent authoritative guidance listed below on their respective effective dates. In February 2016, FASB amended the guidance to account for leases. This guidance is intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The adoption of this guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those years. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes practical expedients that may be elected by entities. Management expects to elect the practical expedients which permit the Registrants to retain their current lease assessment and classifications for existing leases at the effective date and to not apply the new guidance to land easements that exist or expire before the effective date. Management is currently working through an adoption plan which includes the evaluation of lease contracts, new business processes, including changes to current recordkeeping systems, and the need for additional internal controls. Other than an expected increase in assets and liabilities, the full impact of the amended guidance has not been determined. Management will continue to evaluate the impact of this guidance, including any additional clarifying amendments issued during implementation. The amended guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants. In November 2016, FASB amended guidance for certain cash flow issues. The amended guidance requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash. Therefore, amounts generally described as restricted cash and cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The adoption of this guidance was effective for fiscal years beginning after December 15, 2017, including interim periods within those years. This amendment was applied using a retrospective transition method to each period presented. This guidance impacted the presentation of the cash flows statement, but did not have an impact on the results of operations or financial condition of the Registrants. The following tables summarize the changes in the presentation of the Condensed Consolidated Statements of Cash Flows for Cleco and Cleco Power: Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Transfer of cash from restricted accounts, net $ 8,790 $ — Net cash used in investing activities $ (38,112 ) $ (46,902 ) Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents $ (1,558 ) $ (10,348 ) Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period $ 23,077 $ 69,571 Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period $ 21,519 $ 59,223 Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Transfer of cash from restricted accounts, net $ 8,790 $ — Net cash used in investing activities $ (36,762 ) $ (45,552 ) Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents $ (318 ) $ (9,108 ) Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period $ 21,482 $ 67,955 Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period $ 21,164 $ 58,847 In March 2017, FASB amended guidance related to defined benefit pension and other postretirement benefit plans. The new amendment requires an entity to present service cost in the same line item as other current employee compensation costs and to present the remaining components of net benefit cost in a separate line item outside of operating items. The amendment also allows only the service cost component of net benefit cost to be eligible for capitalization within property, plant, and equipment. The non-service costs will continue to be capitalized and recovered from ratepayers as approved by FERC. Beginning January 1, 2018, the non-service costs capitalized for ratemaking purposes were reflected as a regulatory asset or liability for GAAP. The adoption of this guidance was effective for annual periods beginning after December 15, 2017, including interim periods within those years. This amendment was applied retrospectively for the presentation of the service cost in the income statement while the capitalization of the service cost was applied prospectively. This guidance did not have a significant impact on the results of operations, financial condition, or cash flows of the Registrants. The following tables summarize the impact of this guidance on the Condensed Consolidated Statements of Income for Cleco and Cleco Power: Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Other operations expenses $ 31,892 $ 29,327 * Total operating expenses $ 211,703 $ 209,039 Operating income $ 38,798 $ 41,462 Other expense $ (274 ) $ (2,938 ) *Also reflects $0.1 million of Merger transaction and commitment costs that were reported in a separate line item in prior year. Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Other operations expenses $ 31,988 $ 30,264 Total operating expenses $ 209,002 $ 207,278 Operating income $ 44,700 $ 46,424 Other expense $ (274 ) $ (1,998 ) In February 2018, FASB amended guidance that permits, but does not require, companies to reclassify stranded tax effects from the TCJA from AOCI to retained earnings. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2018, including interim periods within those years. Early adoption is permitted. Management is currently evaluating this guidance and the impact it may have on the results of operations, financial condition, or cash flows of the Registrants.

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	3 Months Ended
	Mar. 31, 2018
Regulatory Assets and Liabilities Disclosure [Abstract]
Regulatory Assets and Liabilities	Note 4 — Regulatory Assets and Liabilities Cleco 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 believes these regulatory assets will be fully recoverable; however, if in the future, as a result of regulatory changes or competition, Cleco’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 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 could require discontinuance of the application of the authoritative guidance on regulated operations. The following table summarizes Cleco Power’s regulatory assets and liabilities: (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Regulatory liabilities - deferred taxes, net $ (138,329 ) $ (140,426 ) Mining costs 3,186 3,823 Interest costs 4,410 4,499 AROs 2,689 2,762 Postretirement costs 139,822 142,764 Tree trimming costs 7,579 7,193 Training costs 6,513 6,552 Surcredits, net 1,195 2,173 AMI deferred revenue requirement 4,090 4,227 Emergency declarations 4,004 4,131 Production operations and maintenance expenses 7,226 8,625 AFUDC equity gross-up 71,245 71,205 Acadia Unit 1 acquisition costs 2,310 2,336 Financing costs 8,201 8,293 MISO integration costs 234 468 Coughlin transaction costs 961 968 Corporate franchise tax, net — 153 MATS costs 1,282 2,564 Non-service cost of postretirement benefits 1,037 — Other 255 484 Total regulatory assets 266,239 273,220 Corporate franchise tax, net (169 ) — Accumulated deferred fuel 23,053 13,980 Total regulatory assets, net $ 150,794 $ 146,774 The following table summarizes Cleco’s net regulatory assets and liabilities: (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Total Cleco Power regulatory assets, net $ 150,794 $ 146,774 Cleco Merger adjustments (1) Fair value of long-term debt 145,033 147,145 Postretirement costs 20,878 21,375 Financing costs 8,536 8,623 Debt issuance costs 6,562 6,665 Total Cleco regulatory assets, net $ 331,803 $ 330,582 (1) Cleco regulatory assets include acquisition accounting adjustments as a result of the Merger. Non-service Cost of Postretirement Benefits On January 1, 2018, FASB’s amended guidance related to defined benefit pension and other postretirement plans became effective. The amendment allows only the service cost component of net benefit cost to be eligible for capitalization within property, plant, and equipment. The non-service costs will continue to be capitalized and recovered from ratepayers as approved by FERC . Beginning January 1, 2018, the non-service cost previously eligible for capitalization into property, plant, and equipment will be deferred to a regulatory asset and amortized over the estimated lives of the respective assets. For more information on FASB’s guidance related to defined benefit pension and other postretirement plans, see Note 3 — “Recent Authoritative Guidance.”

Fair Value Accounting

Fair Value Accounting	3 Months Ended
	Mar. 31, 2018
Fair Value Disclosures [Abstract]
Fair Value Accounting	Note 5 — Fair Value Accounting The amounts reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2018 , and December 31, 2017 , 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 MAR. 31, 2018 AT DEC. 31, 2017 (THOUSANDS) CARRYING VALUE* FAIR VALUE CARRYING VALUE* FAIR VALUE Long-term debt $ 2,905,222 $ 2,924,772 $ 2,866,955 $ 2,921,325 * The carrying value of long-term debt does not include deferred issuance costs of $11.3 million and $11.6 million at March 31, 2018 , and December 31, 2017 , respectively. Cleco Power AT MAR. 31, 2018 AT DEC. 31, 2017 (THOUSANDS) CARRYING VALUE* FAIR VALUE CARRYING VALUE* FAIR VALUE Long-term debt $ 1,410,188 $ 1,555,341 $ 1,369,810 $ 1,535,234 * The carrying value of long-term debt does not include deferred issuance costs of $8.9 million and $9.1 million at March 31, 2018 , and December 31, 2017 , respectively. 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. The following tables disclose for Cleco and Cleco Power the fair value of financial assets and liabilities measured on a recurring basis: Cleco CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE (THOUSANDS) AT MAR. 31, 2018 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) AT DEC. 31, 2017 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) Asset description Institutional money market funds $ 198,446 $ — $ 198,446 $ — $ 144,302 $ — $ 144,302 $ — FTRs 4,828 — — 4,828 7,396 — — 7,396 Total assets $ 203,274 $ — $ 198,446 $ 4,828 $ 151,698 $ — $ 144,302 $ 7,396 Liability description FTRs $ 545 $ — $ — $ 545 $ 352 $ — $ — $ 352 Total liabilities $ 545 $ — $ — $ 545 $ 352 $ — $ — $ 352 Cleco Power CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE (THOUSANDS) AT MAR. 31, 2018 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) AT DEC. 31, 2017 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) Asset description Institutional money market funds $ 151,225 $ — $ 151,225 $ — $ 95,681 $ — $ 95,681 $ — FTRs 4,828 — — 4,828 7,396 — — 7,396 Total assets $ 156,053 $ — $ 151,225 $ 4,828 $ 103,077 $ — $ 95,681 $ 7,396 Liability description FTRs $ 545 $ — $ — $ 545 $ 352 $ — $ — $ 352 Total liabilities $ 545 $ — $ — $ 545 $ 352 $ — $ — $ 352 The following table summarizes 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: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 Beginning balance $ 7,044 $ 7,683 Unrealized gains* 1,617 2,104 Purchases 371 275 Settlements (4,749 ) (5,644 ) Ending balance $ 4,283 $ 4,418 * Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions as of March 31, 2018 , and December 31, 2017 : FAIR VALUE VALUATION TECHNIQUE SIGNIFICANT UNOBSERVABLE INPUTS FORWARD PRICE RANGE (THOUSANDS, EXCEPT FORWARD PRICE RANGE) ASSETS LIABILITIES LOW HIGH FTRs at Mar. 31, 2018 $ 4,828 $ 545 RTO auction pricing FTR price - per MWh $ (7.21 ) $ 7.21 FTRs at Dec. 31, 2017 $ 7,396 $ 352 RTO auction pricing FTR price - per MWh $ (2.95 ) $ 6.33 Cleco utilizes different valuation techniques for fair value calculations. In order to measure the fair value for Level 1 assets and liabilities, Cleco obtains the closing price from published indices in active markets for the various instruments and multiplies this price by the appropriate number of instruments held. Cleco’s Level 2 fair values are determined by obtaining the closing price of similar assets and liabilities from published indices in active markets and then discounting the price to the current period using a U.S. Treasury published interest rate as a proxy for a risk-free rate of return. Level 3 fair values occur in situations in which there is little, if any, market activity for the asset or liability at the measurement date. Cleco’s Level 3 assets and liabilities are valued using RTO auction prices. 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. At March 31, 2018 , 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 institutional money market funds were reported on Cleco’s Condensed Consolidated Balance Sheets in cash and cash equivalents, current restricted cash and cash equivalents, and non-current restricted cash and cash equivalents of $172.5 million , $6.7 million , and $19.2 million , respectively, at March 31, 2018 , and $111.1 million , $13.1 million , and $20.1 million , respectively, at December 31, 2017 . At Cleco Power, the institutional money market funds were reported on Cleco Power’s Condensed Consolidated Balance Sheets in cash and cash equivalents, current restricted cash and cash equivalents, and non-current restricted cash and cash equivalents of $125.3 million , $6.7 million , and $19.2 million , respectively, at March 31, 2018 , and $62.5 million , $13.1 million , and $20.1 million , respectively, at December 31, 2017 . 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 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 Power’s FTRs were priced 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 pricing available comes from MISO auctions, which occur monthly in the Multi-Period Monthly Auction. During the three months ended March 31, 2018 , and the year ended December 31, 2017 , Cleco did no t experience any transfers between levels within the fair value hierarchy. Commodity Contracts The following table presents the fair values of derivative instruments and their respective line items as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2018 , and December 31, 2017 : DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS (THOUSANDS) BALANCE SHEET LINE ITEM AT MAR. 31, 2018 AT DEC. 31, 2017 Commodity-related contracts FTRs Current Energy risk management assets $ 4,828 $ 7,396 Current Other current liabilities 545 352 Commodity-related contracts, net $ 4,283 $ 7,044 The following table presents the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2018 , and 2017 : AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) DERIVATIVES LINE ITEM 2018 2017 Commodity contracts FTRs (1) Electric operations $ 18,150 $ 9,163 FTRs (1) Power purchased for utility customers (5,667 ) (4,665 ) Total $ 12,483 $ 4,498 (1) For the three months ended March 31, 2018 , and 2017, unrealized gains associated with FTRs of $1.6 million and $2.1 million , respectively, were reported through Accumulated deferred fuel on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. The total volume of FTRs that Cleco Power had outstanding at March 31, 2018 , and December 31, 2017 , was 3.8 million MWh and 9.0 million MWh, respectively.

Debt

Debt	3 Months Ended
	Mar. 31, 2018
Debt Disclosure [Abstract]
Debt	Note 6 — Debt On December 18, 2017, Cleco Power entered into an agreement for the issuance and sale in a private placement of $175.0 million aggregate principal amount of senior notes. The senior notes were issued in two tranches. The first tranche was issued on December 18, 2017, with principal amounts of $25.0 million at an interest rate of 2.94% and $100.0 million at an interest rate of 3.08% , with final maturity dates of December 16, 2022, and 2023, respectively. The second tranche was issued on March 26, 2018, with principal amounts of $50.0 million at an interest rate of 3.17% , with a final maturity date of December 16, 2024. The proceeds from the issuance and sale were used for capital investments and general utility purposes. On February 6, 2018, Cleco Power entered into a debt commitment letter in connection with the Purchase and Sale Agreement. For more information on the debt commitment letter, see Note 16 — “Plan of Acquisition.”

Pension Plan and Employee Benef

Pension Plan and Employee Benefits	3 Months Ended
	Mar. 31, 2018
Retirement Benefits [Abstract]
Pension Plan and Employee Benefits	Note 7 — 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. Benefits under the plan reflect an employee’s years of service, age at retirement, and highest total average compensation for any consecutive five calendar years during the last ten years of employment with Cleco. Cleco’s policy is to base its contributions to the employee pension plan upon actuarial computations utilizing the projected unit credit method, subject to the IRS’s full funding limitation. Cleco did not make any required or discretionary contributions to the pension plan in 2017 and does not expect to make any in 2018. The required contributions are driven by liability funding target percentages set by law which could cause the required contributions to be uneven among the years. The ultimate amount and timing of the contributions may be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator. 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. Cleco recognizes expected costs of Other Benefits during the periods in which the benefits are earned. The non-service components of net periodic pension and Other Benefits cost are included in Other expense within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. Net periodic pension and Other Benefits cost for the three months ended March 31, 2018 , and 2017 were as follows: PENSION BENEFITS OTHER BENEFITS FOR THE THREE MONTHS ENDED MAR. 31, FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 2018 2017 Components of periodic benefit costs Service cost $ 2,393 $ 2,225 $ 338 $ 385 Interest cost 5,183 5,358 357 403 Expected return on plan assets (5,938 ) (6,138 ) — — Amortizations Prior period service credit (18 ) (18 ) — — Net loss (gain) 2,960 2,413 5 (3 ) Net periodic benefit cost $ 4,580 $ 3,840 $ 700 $ 785 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 months ended March 31, 2018 , and 2017 , was $0.5 million and $0.4 million , respectively. Cleco Holdings is the plan sponsor for the Other Benefits 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 months ended March 31, 2018 , and 2017, was $0.8 million and $0.9 million , respectively. The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at March 31, 2018 , and December 31, 2017 , were as follows: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current $ 4,061 $ 4,061 Non-current $ 38,684 $ 39,142 Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current $ 3,525 $ 3,525 Non-current $ 33,648 $ 34,033 SERP Certain Cleco officers are covered by SERP. In 2014, SERP was closed to new participants; however, with regard to current SERP participants, including former employees or their beneficiaries, all terms of SERP will continue, other than as described below. SERP is a non-qualified, non-contributory, defined benefit pension plan. Generally, benefits under the plan reflect an employee’s years of service, age at retirement and the sum of (a) the highest base salary paid out over the last five calendar years and (b) the average of the three highest cash bonuses paid during the 60 months prior to retirement. SERP benefits are reduced by retirement benefits received from any other defined benefit pension plan, supplemental executive retirement plan, or Cleco contributions under the enhanced 401(k) Plan to the extent such contributions exceed the amount the employee would have received under the terms of the original 401(k) Plan. In accordance with the SERP plan document and the Merger Agreement, four executive officers received enhanced benefits, and upon termination of employment, two of these executive officers received accelerated vesting. Another executive officer received enhanced SERP benefits, net of other postretirement benefits, as part of a separation agreement. Two executive officers’ SERP benefits were capped as of December 31, 2017, with regard to final compensation; however, adjustments will continue with regard to age and tenure with Cleco. Additionally, these executive officers had their annual bonuses set at target rather than actual awards for the years 2016 and 2017 for the average incentive award portion of their SERP benefit calculation. A third executive officer’s SERP benefit amount will be set at a specified amount based upon the year of separation. Management will review current market trends as it evaluates Cleco’s future compensation strategy. Cleco does not fund the SERP liability, but instead pays for current benefits out of the 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 the general cash available of the respective companies that employed the officer. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator. The non-service components of net periodic benefit cost related to SERP are included in Other expense within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. Net periodic benefit cost related to SERP for the three months ended March 31, 2018 , and 2017 , were as follows: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 Components of periodic benefit costs Service cost $ 105 $ 145 Interest cost 760 800 Amortizations Prior period service credit (35 ) (57 ) Net loss 585 419 Net periodic benefit cost 1,415 1,307 Special/contractual termination benefits — 315 Total benefit cost $ 1,415 $ 1,622 There was a remeasurement of SERP on March 30, 2017, to reflect a special termination benefit resulting from an executive officer’s separation agreement. On the date of the remeasurement, the discount rate decreased from 4.22% to 4.08% . This remeasurement resulted in a special termination benefit for the executive officer of $0.3 million . The total expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income was $0.3 million for both the three months ended March 31, 2018 , and 2017 . 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 March 31, 2018 , and December 31, 2017 , were as follows: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current $ 4,471 $ 4,471 Non-current $ 79,637 $ 79,868 Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current $ 929 $ 929 Non-current $ 16,560 $ 16,589 401(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 401(k) Plan is voluntary, and all active Cleco employees are eligible to participate. Cleco’s 401(k) Plan expense for the three months ended March 31, 2018 , and 2017 , was as follows: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 401(k) Plan expense $ 2,063 $ 1,668 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 months ended March 31, 2018 , and 2017 , was as follows: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 401(k) Plan expense $ 402 $ 279

Income Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2018
Income Tax Disclosure [Abstract]
Income Taxes	Note 8 — Income Taxes Effective Tax Rates The following tables summarize the effective income tax rates for Cleco and Cleco Power for the three months ended March 31, 2018 , and 2017 : Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2018 2017 Effective tax rate 20.9 % 33.1 % Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2018 2017 Effective tax rate 23.5 % 35.6 % For the three months ended March 31, 2018 , and 2017 , the effective income tax rates for both Cleco and Cleco Power were different than the federal statutory rate primarily due to permanent tax differences, the flowthrough of state tax benefits, including AFUDC equity, and state tax expense. Uncertain Tax Positions Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. At March 31, 2018 , and December 31, 2017 , Cleco and Cleco Power had no interest payable related to uncertain tax positions. For the three months ended March 31, 2018 , and 2017 , Cleco and Cleco Power had no interest expense related to uncertain tax positions. At March 31, 2018 , Cleco had no liability for uncertain tax positions. Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of March 31, 2018 , 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. The federal income tax years that remain subject to examination by the IRS are 2014, 2015, and 2016. Beginning with the 2013 tax year, Cleco entered into the IRS’s Compliance Assurance Process which allows taxpayers to work collaboratively with an IRS team to identify and resolve potential tax issues before the federal tax return is filed each year. Cleco must apply for admission to the program each year. Cleco has been approved for the Compliance Assurance Process through the 2018 tax year. The state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2014, 2015, and 2016. Cleco classifies income tax penalties as a component of other expense. For the three months ended March 31, 2018 , and 2017 , no penalties were recognized. 2017 Tax Reform On December 22, 2017, the President signed into law the TCJA. The TCJA includes significant changes to the Internal Revenue Code, as amended, including amendments which significantly change the taxation of business entities and includes specific provisions related to rate regulated activities, including Cleco Power. The most significant change that impacts Cleco is the reduction in the corporate federal income tax rate from 35% to 21% . The SEC Staff has recognized the complexity of reflecting the impacts of the TCJA and issued guidance which clarifies accounting for income taxes if information is not yet available or complete and provides up to one year to complete the required analysis and accounting (the measurement period). The Registrants have made a reasonable estimate for the measurement and accounting of certain effects of the TCJA, which were reflected in the December 31, 2017, financial statements. The accounting for these provisional items decreased deferred income tax expense for Cleco and Cleco Power by $46.3 million and $14.3 million , respectively, for the year ended December 31, 2017. The TCJA also resulted in a decrease in the accumulated deferred income tax liability for Cleco and Cleco Power by $394.9 million and $362.9 million , respectively, at December 31, 2017. For the three months ended March 31, 2018 , there were no adjustments in the accumulated deferred income tax liability related to the TCJA for Cleco or Cleco Power. The impacts of the TCJA discussed above, including the effects on income tax expense, regulatory liabilities, and effects on future periods, are provisional and subject to change. The accounting is not complete due to the timing of the final passage of the TCJA, the complexity of the TCJA, the complexity of remeasuring ADIT, and the uncertainty of regulatory treatment. Additional analysis of the TCJA, the inventory of items that give rise to temporary differences, and additional analysis of items requiring normalization is required before accounting for the TCJA is considered complete under the authoritative guidance for income taxes. Cleco expects any final adjustments to the provisional amounts to be recorded by the fourth quarter of 2018, which could have a material adverse effect on the results of operations of Cleco.

Disclosures about Segments

Disclosures about Segments	3 Months Ended
	Mar. 31, 2018
Segment Reporting [Abstract]
Disclosures about Segments	Note 9 — Disclosures about Segments Cleco’s reportable segment is based on its method of internal reporting, which disaggregates business units by its first-tier subsidiary. Cleco Power, the reportable segment, engages in business activities from which it earns revenue and incurs expenses. Segment managers report periodically to Cleco’s CEO with discrete financial information and, at least quarterly, present discrete financial information to Cleco and Cleco Power’s Boards of Managers. The reportable segment prepares budgets that are presented to and approved by Cleco and Cleco Power’s Boards of Managers. The column shown as Other in the chart below includes the holding company, a shared services subsidiary, two transmission interconnection facility subsidiaries, an investment subsidiary, and a subsidiary formed to facilitate the Purchase and Sale Agreement with NRG Energy and NRG South Central. On December 29, 2017, Cleco sold the transmission assets owned by Attala and Perryville, the two subsidiaries that owned and operated the transmission interconnection facilities. After December 29, 2017, the remaining operations of Attala and Perryville were minimal. On February 6, 2018, Cleco Cajun entered into the Purchase and Sale Agreement with NRG Energy and NRG South Central. Upon the expected closing of the transaction, Cleco anticipates Cleco Cajun will be a new reportable segment. For more information on the Purchase and Sale Agreement and related transactions, see Note 16 — “Plan of Acquisition.” The financial results in the table below are presented on an accrual basis. Management evaluates the performance of its segment and allocates resources to it based on segment profit and the requirements to implement new strategic initiatives and projects to meet current business objectives. Material intercompany transactions occur on a regular basis. These intercompany transactions relate primarily to joint and common administrative support services. SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) CLECO POWER OTHER ELIMINATIONS CONSOLIDATED Revenue Electric operations $ 264,631 $ (2,420 ) $ — $ 262,211 Other operations 22,195 1 — 22,196 Electric customer credits (7,647 ) — — (7,647 ) Affiliate revenue 208 15,669 (15,877 ) — Operating revenue, net $ 279,387 $ 13,250 $ (15,877 ) $ 276,760 Depreciation and amortization $ 40,388 $ 2,119 $ — $ 42,507 Interest charges $ 17,656 $ 13,549 $ (48 ) $ 31,157 Interest income $ 641 $ 190 $ (48 ) $ 783 Federal and state income tax expense (benefit) $ 7,997 $ (5,135 ) $ — $ 2,862 Net income (loss) $ 26,004 $ (15,142 ) $ (1 ) $ 10,861 Additions to property, plant, and equipment $ 63,343 $ 790 $ — $ 64,133 Equity investment in investees $ 18,172 $ — $ — $ 18,172 Goodwill $ 1,490,797 $ — $ — $ 1,490,797 Total segment assets $ 5,722,284 $ 618,513 $ (30,816 ) $ 6,309,981 2017 (THOUSANDS) CLECO POWER OTHER ELIMINATIONS CONSOLIDATED Revenue Electric operations $ 237,553 $ (3,497 ) $ — $ 234,056 Other operations 16,365 515 — 16,880 Electric customer credits (435 ) — — (435 ) Affiliate revenue 219 14,734 (14,953 ) — Operating revenue, net $ 253,702 $ 11,752 $ (14,953 ) $ 250,501 Depreciation and amortization $ 38,758 $ 2,093 $ — $ 40,851 Interest charges $ 18,104 $ 13,681 $ (67 ) $ 31,718 Interest income $ 266 $ 113 $ (67 ) $ 312 Federal and state income tax expense (benefit) $ 9,855 $ (6,748 ) $ — $ 3,107 Net income (loss) $ 17,854 $ (11,562 ) $ — $ 6,292 Additions to property, plant, and equipment $ 46,744 $ 1,146 $ — $ 47,890 Equity investment in investees (1) $ 18,172 $ — $ — $ 18,172 Goodwill (1) $ 1,490,797 $ — $ — $ 1,490,797 Total segment assets (1) $ 5,679,538 $ 619,943 $ (21,099 ) $ 6,278,382 (1) Balances as of December 31, 2017

Regulation and Rates

Regulation and Rates	3 Months Ended
	Mar. 31, 2018
Regulated Operations [Abstract]
Regulation and Rates	Note 10 — Regulation and Rates Transmission ROE Two complaints were filed with FERC seeking to reduce the ROE component of the transmission rates that MISO transmission owners, including Cleco, may collect under the MISO tariff. As of March 31, 2018 , Cleco Power h ad $2.1 million a ccrued for ROE reductions, including accrued interest. For more information on the ROE complaints, see Note 12 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — Transmission ROE.” FRP Cleco Power’s annual retail earnings are subject to an FRP that was approved by the LPSC in June 2014. Under the terms of the FRP, Cleco Power is allowed 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% 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. Credits are typically included on customers’ bills the following summer, but the amount and timing of the refunds is ultimately subject to LPSC approval. Cleco Power will file an application with the LPSC for a new FRP by June 30, 2019, with anticipated new rates being effective July 1, 2020. Cleco Power must file annual monitoring reports no later than October 31 for the 12-month period ended June 30. On October 31, 2017, Cleco Power filed its monitoring report for the 12-month period ended June 30, 2017, which indicated that no refund was due as a result of the FRP and $1.2 million was due as a result of the cost of service savings from the Merger Commitments. On March 5, 2018, Cleco Power responded to two sets of data requests from the LPSC for the 2017 monitoring report. On April 24, 2018, Cleco Power responded to a third set of data requests for the 2017 monitoring report. As of March 31, 2018, Cleco Power had $2.1 million accrued for the cost of service savings refund. 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 can be implemented to mitigate reliability issues. One mitigating factor that has been identified is Cleco Power’s Terrebonne to Bayou Vista Transmission project, which is expected to be complete by the first quarter of 2019. In the second quarter of 2017, MISO began allocating SSR costs to the load serving entities that require the operation of the SSR unit for reliability purposes, including Cleco Power. Cleco Power had a 12-month SSR agreement for the period April 1, 2017, to March 31, 2018. In January 2018, another study was performed by MISO, and it was determined that an SSR agreement will be needed for the period April 1, 2018, until the sooner of the in-service date of the Terrebonne to Bayou Vista Transmission project or March 31, 2019. During this time, Cleco Power will continue to operate Teche Unit 3. Cleco Power filed with FERC for its approval to collect $20.3 million and $11.8 million annually in SSR payments from MISO for the first and second SSR agreements, respectively. The SSR payments include recovering operations and maintenance expenses, administrative and general expenses, taxes, depreciation, capital expenditures, and carrying charges, all of which are related to Teche Unit 3 for the period of the SSR agreements. At the end of the SSR period, when Teche Unit 3 is retired, any SSR payments received from MISO for capital expenditures paid by third parties will be credited to property, plant, and equipment. As of March 31, 2018, Cleco Power had $4.3 million accrued for SSR payments received for capital expenditures related to Teche Unit 3. In the second quarter of 2017, Cleco Power began receiving the monthly SSR payments from MISO, subject to refund pending review and approval by FERC. On July 20, 2017, Cleco Power, FERC staff, and intervenors met at the first settlement conference and set a procedural schedule for data requests between parties. On July 27, 2017, Cleco Power received five sets of informal data requests from FERC staff and intervenors. The second settlement conference was held on February 22, 2018; however, a settlement was not reached. Cleco Power is unable to determine when a binding FERC order will be issued. At the end of the SSR agreement, Cleco Power will have the option to rescind the Attachment Y requesting retirement of Teche Unit 3. If this option is exercised, Cleco Power may be required to refund recoverable capital expenditures plus interest. Management does not expect to be required to refund any portion of these costs. TCJA On February 21, 2018, the LPSC directed utilities, including Cleco Power, to provide considerations of the appropriate manner to flowthrough to ratepayers the benefits of the reduction in corporate income taxes as a result of the TCJA. Cleco Power filed comments with the LPSC on March 12, 2018, which included among other things, a refund to customers for the differences in the cumulative federal and state income tax rate of 38% prior to the TCJA, versus the 26% cumulative federal and state income tax rate effective after the TCJA. As a result, Cleco Power began accruing an estimated reserve for the change in the tax rate beginning January 1, 2018, and will continue through June 30, 2018. Cleco Power recommended refunding this amount to customers on September 2018 bills based on July 2018 usage, pending LPSC review and approval. At March 31, 2018, Cleco Power had $7.3 million accrued for the estimated federal tax-related benefits from the TCJA. For the period July 1, 2018, to June 30, 2019, Cleco Power has proposed that its annual FRP filing reflect the change in the tax rate.

Variable Interest Entities

Variable Interest Entities	3 Months Ended
	Mar. 31, 2018
Variable Interest Entity, Not Primary Beneficiary, Disclosures [Abstract]
Variable Interest Entities	Note 11 — 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 March 31, 2018 , consisted of its equity investment of $18.2 million . The following table presents the components of Cleco Power’s equity investment in Oxbow: INCEPTION TO DATE (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Purchase price $ 12,873 $ 12,873 Cash contributions 6,399 6,399 Dividends (1,100 ) (1,100 ) Total equity investment in investee $ 18,172 $ 18,172 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 MAR. 31, 2018 AT DEC. 31, 2017 Oxbow’s net assets/liabilities $ 36,345 $ 36,345 Cleco Power’s 50% equity $ 18,172 $ 18,172 Cleco Power’s maximum exposure to loss $ 18,172 $ 18,172 The following table contains summarized financial information for Oxbow: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 Operating revenue $ 863 $ 1,073 Operating expenses 863 1,073 Income before taxes $ — $ — DHLC mines lignite reserves at Oxbow through the Amended Lignite Mining Agreement. The lignite reserves are intended to be used to provide fuel to the Dolet Hills Power Station. 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	3 Months Ended
	Mar. 31, 2018
Commitments and Contingencies Disclosure [Abstract]
Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees Litigation Devil’s Swamp In October 2007, Cleco received a Special Notice for Remedial Investigation and Feasibility Study (RI/FS) from the EPA pursuant to the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (also known as the Superfund statute) for a facility known as the Devil’s Swamp Lake site located just northwest of Baton Rouge, Louisiana. The special notice requested that Cleco and Cleco Power, along with many other listed potentially responsible parties (PRP), enter into negotiations with the EPA for the performance of an RI/FS at the Devil’s Swamp Lake site. The EPA identified Cleco as one of many companies that sent PCB wastes for disposal to the site. The EPA proposed to add the Devil’s Swamp Lake site to the National Priorities List on March 8, 2004, based on the release of PCBs to fisheries and wetlands located on the site, but no final listing decision has yet been made. The PRPs began discussing a potential proposal to the EPA in February 2008. The EPA issued a Unilateral Administrative Order to two PRPs, Clean Harbors, Inc. and Baton Rouge Disposal, to conduct an RI/FS in December 2009. The Tier 1 part of the study was completed in June 2012. Field activities for the Tier 2 investigation were completed in July 2012. The draft Tier 2 remedial investigation report was submitted in December 2014. In 2015, remedial investigation activities included the collection and analysis of sediment, crawfish, and fish tissue samples. After reviewing the sample analysis, in August 2015, the Louisiana Department of Health and Hospitals updated the advisory for the area to advise that fish and crawfish from the area should not be eaten. The final Tier 2 remedial investigation report was made public in December 2015. Currently, the study/remedy selection task continues, and there is no record of a decision. Therefore, management is unable to determine how significant Cleco’s share of the costs associated with the RI/FS and possible response action at the site, if any, may be and whether this will have a material impact on the results of operations, financial condition, or cash flows of the Registrants. Merger In connection with the 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 Merger at a price that allegedly undervalued Cleco, and failing to disclose material information about the Merger. The petitions also alleged that Cleco Partners, Cleco Corporation, Merger Sub, and in some cases, certain of the investors in Cleco Partners, either aided and abetted or entered into a civil conspiracy to advance those supposed breaches of duty. The petitions seek 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. 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 Consolidated Amended Petition). The consolidated action named Cleco Corporation, its directors, Cleco Partners, and Merger Sub as defendants. The Consolidated Amended Petition alleged, among other things, that Cleco Corporation’s directors breached their fiduciary duties to Cleco’s shareholders and grossly mismanaged Cleco by approving the Merger Agreement because it allegedly did not value Cleco adequately, failing to structure a process through which shareholder value would be maximized, engaging in self-dealing by ignoring conflicts of interest, and failing to disclose material information about the Merger. The Consolidated Amended Petition further alleged that all defendants conspired to commit the breaches of fiduciary duty. Cleco believes that the allegations of the Consolidated Amended Petition are without merit and that it has substantial meritorious defenses to the claims set forth in the Consolidated Amended Petition. The three actions filed in the Civil District Court for Orleans Parish are 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). Both the Butler and Cashen actions name Cleco Corporation, its directors, Cleco Partners, Merger Sub, MIRA, bcIMC, and John Hancock Financial as defendants. The Creative Life Services action names Cleco Corporation, its directors, Cleco Partners, Merger Sub, MIRA, and Macquarie Infrastructure Partners III, L.P., as defendants. In December 2014, the plaintiff in the Butler action filed an Amended Class Action Petition for Damages. Each petition alleged, among other things, that the members of Cleco Corporation’s Board of Directors breached their fiduciary duties to Cleco’s shareholders by approving the Merger Agreement because it allegedly does not value Cleco adequately, failing to structure a process through which shareholder value would be maximized and engaging in self-dealing by ignoring conflicts of interest. The Butler and Creative Life Services petitions also allege that the directors breached their fiduciary duties by failing to disclose material information about the Merger. Each petition further alleged that Cleco, Cleco Partners, Merger Sub, and certain of the investors in Cleco Partners aided and abetted the directors’ breaches of fiduciary duty. 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. In February 2015, the Ninth Judicial District Court for Rapides Parish held a hearing on a motion for preliminary injunction filed by plaintiffs Moore , L’Herisson , and Trahan seeking to enjoin the shareholder vote for approval of the Merger Agreement. Following the hearing, the Court denied the plaintiffs’ motion. In June 2015, three of the plaintiffs filed their Second Consolidated Amended Verified Derivative and Class Action Petition. This will be considered according to a schedule established by the Ninth Judicial District Court for Rapides Parish. Cleco filed exceptions seeking dismissal of the amended petition in July 2015. In March 2016, the plaintiffs filed their Third Consolidated Amended Verified Derivative Petition for Damages and Preliminary and Permanent Injunction. In May 2016, the plaintiffs filed their Fourth Verified Consolidated Amended Class Action Petition. This petition eliminated the request for preliminary and permanent injunction and also named an additional executive officer as a defendant. Cleco filed exceptions seeking dismissal of the amended Petition. A hearing was held on September 15, 2016, and on September 26, 2016, the District Court granted the exceptions filed by Cleco 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. The Third Circuit Court of Appeal heard oral arguments in the case in September 2017. In December 2017, the Third Circuit Court of Appeal issued an order reversing and remanding the case to the District Court for further proceedings. On January 12, 2018, Cleco filed a writ with the Louisiana Supreme Court seeking review of the Third Circuit Court of Appeal’s decision. On March 2, 2018, the Louisiana Supreme Court denied the writ. 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. Sabine River Flood In March 2017, Cleco was served with a summons in Perry Bonin, Ace Chandler, and Michael Manuel, et al v. Sabine River Authority of Texas and Sabine River Authority of Louisiana , No. B-160173-C. The action was filed in the 163rd Judicial District Court for Orange County, Texas, and relates to flooding that occurred in Texas and Louisiana in March 2016. The plaintiffs have alleged that the flooding was the result of the release of water from the Toledo Bend spillway gates into the Sabine River. While the plaintiffs have made numerous allegations, they have specifically alleged that Cleco Power, included as one of several companies and governmental bodies, failed to repair one of the two hydroelectric generators at the Toledo Bend Dam, which in turn contributed to the flooding. Cleco Power does not operate the hydroelectric generator. The suit was removed to federal court in Texas. The new federal case is Perry Bonin, et al. v. Sabine River Authority of Texas et al. , No. 17-cv-134, U.S. District Court for the Eastern District of Texas ( Bonin Case ). The plaintiffs moved to remand the case to state court, but the district court found that the case raises a substantial federal question and denied the motion to remand. Cleco Power, along with its co-defendants, filed a motion to dismiss on various grounds, primarily arguing that the plaintiffs’ claims are preempted because they infringe on FERC’s exclusive control of dam operations. The district court granted the motion to dismiss in part, declining to rule on some of the arguments raised by the defendants, and granted the plaintiffs leave to amend their complaint. The plaintiffs filed a Fifth Amended Complaint in March 2018. Cleco Power filed a new motion to dismiss the plaintiffs’ claims. The plaintiffs have not yet responded to Cleco Power’s motion. On March 7, 2018, approximately 26 other individual plaintiffs filed a petition against Cleco Power and other defendants in Larry Addison, et al. v. Sabine River Authority of Texas, et al. , No. D180096-C. The action was filed in the 260th Judicial District Court for Orange County, Texas. The defendants removed the case to federal court on April 6, 2018. The new federal case is Larry Addison, et al. v. Sabine River Authority of Texas, et al ., No. 17-cv-153, U.S. District Court for the Eastern District of Texas. The allegations are essentially identical to those in the Bonin Case . On April 13, 2018, Cleco Power filed a motion to dismiss on the same grounds that previously were successful in the Bonin Case . The plaintiffs have not yet responded to Cleco Power’s motion. Management believes that both cases, as they relate to Cleco Power, have no merit. LPSC Audits Fuel Audit Generally, the cost of fuel used for electric generation and the cost of power purchased for utility customers 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. On March 13, 2018, Cleco Power received notice of an FAC audit from the LPSC for the period of January 1, 2016, to December 31, 2017. The total amount of fuel expense included in the audit is $536.2 million . Periods subsequent to December 31, 2017, are also subject to audit. On April 27, 2018, Cleco Power received its first set of data requests from the LPSC. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to this audit. 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. Environmental Audit In 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides for an EAC to recover from customers certain costs of environmental compliance. The costs eligible for recovery are 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. Cleco Power currently has EAC filings for 2016 and thereafter that are 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. Cleco Power incurs environmental compliance expenses for reagents associated with the compliance standards of MATS. In June 2015, the U.S. Supreme Court remanded the MATS rule to the D.C. Circuit Court of Appeals. In December 2015, the D.C. Circuit Court of Appeals remanded the rule to the EPA; however, the D.C. Circuit Court of Appeals did not vacate this rule. In April 2016, the EPA released a final supplemental finding that, even considering costs, it is appropriate and necessary to regulate hazardous air pollutants. By the June 2016 deadline, six petitions were filed with the U.S. Court of Appeals for the D.C. Circuit Court of Appeals for review of the EPA’s findings. At the request of the EPA, in April 2017, the court issued an order holding the cases in abeyance pending the EPA’s review of its supplemental finding. These expenses are also eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC. FERC Audit On March 13, 2018, the Division of Audits and Accounting within the Office of Enforcement of FERC initiated an audit of Cleco Power for the period January 1, 2014, to the present. No data requests have been received and management is unable to determine the outcome or timing of the audit. Transmission ROE Two complaints were filed with FERC seeking to reduce the ROE component of the transmission rates that MISO transmission owners, including Cleco, may collect under the MISO tariff. The complaints sought to reduce the 12.38% ROE used in MISO’s transmission rates to a proposed 6.68% . The first complaint, filed in November 2013, was for the period November 2013 through February 2015. In September 2016, FERC issued a Final Order in response to the first complaint establishing a 10.32% ROE. In February 2017, $1.2 million of refunds relating to the first complaint were submitted to MISO. The second complaint, filed in February 2015, was for the period February 2015 through May 2016. In June 2016, an ALJ issued an initial decision in the second rate case docket recommending a 9.70% base ROE. Cleco Power is unable to determine when a binding FERC order will be issued on the second ROE complaint. 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 is delayed until the resolution of the ROE complaint proceedings. As of March 31, 2018 , Cleco Power had $2.1 million accrued, including interest, for potential reductions to the ROE. Management believes a reduction in the ROE, as well as any additional refund, will not have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants. 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 in the event of a negative outcome may be in excess of amounts currently accrued. Management regularly analyzes current information and, as of March 31, 2018 , believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters are $4.6 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 standing 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 facility in 2005. The remaining indemnifications relate to environmental matters that may have been present prior to closing. These remaining indemnifications have no limitations to time. 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 limitations as to time 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 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. The maximum projected payment by Cleco Power under this guarantee is estimated to be $106.5 million ; however, the Amended Lignite Mining Agreement does not contain a cap. The projection is based on the forecasted loan and lease obligations to be incurred by DHLC, primarily for purchases of equipment. Cleco Power has the right to dispute the incurrence of loan and lease obligations through the review of the mining plan before the incurrence of such loan and lease obligations. The Amended Lignite Mining Agreement is not expected to terminate pursuant to its terms until 2036 and 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. 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 NMTC Fund In 2008, Cleco Holdings and US Bancorp Community Development (USBCDC) formed the NMTC Fund. Cleco Holdings has a 99.9% membership interest in the NMTC Fund and USBCDC has a 0.1% interest. The purpose of the NMTC Fund is to invest in projects located in qualified active low-income communities that are underserved by typical debt capital markets. These investments are designed to generate NMTCs and Historical Rehabilitation tax credits. The NMTC Fund was later amended to include renewable energy investments. The majority of the energy investments qualify for grants under Section 1603 of the ARRA. The tax benefits received from the NMTC Fund reduce the federal income tax obligations of Cleco Holdings. In total, Cleco Holdings contributed $285.5 million of equity contributions to the NMTC Fund and will receive at least $303.8 million in the form of tax credits, tax losses, capital gains/losses, earnings, and cash over the 10 -year life of the investment. The difference between equity contributions and total benefits received were recognized over the life of the NMTC Fund as net tax benefits were delivered. As of March 31, 2018 , the amount of tax benefits delivered was $18.3 million . Due to the right of offset, the investment and associated debt are presented in Other deferred charges, on Cleco’s Condensed Consolidated Balance Sheet. By using the cost method for investments, the gross investment amortization expense will be recognized over a ten -year period. The basis of the investment is reduced by the grants received under Section 1603 of the ARRA, which allow certain projects to receive a federal grant in lieu of tax credits, and other cash. Periodic amortization of the investment and the deferred taxes generated by the basis reduction temporary difference are included as components of income tax expense. Fuel Transportation Agreement In 2012, Cleco Power entered into an amended agreement with Savage Services for 42 dedicated barges used to transport petroleum coke and limestone to Madison Unit 3. The amended agreement met the accounting definition of a capital lease until its expiration on August 31, 2017. In September 2017, Cleco Power entered into an operating lease that automatically renewed on a month-to-month basis until terminated by either party for use of the 42 barges. On April 2, 2018, the operating lease was terminated and Cleco Power entered into a new agreement with Savage Inland Marine for continued use of the 42 dedicated barges through March 2033. The new agreement meets the accounting definition of a capital lease. Other Cleco has accrued for liabilities related to third parties, employee medical benefits, and AROs. Risks and Uncertainties Cleco could be subject to possible adverse consequences if Cleco’s counterparties fail to perform their obligations or if Cleco or its affiliates are not in compliance with loan agreements or bond indentures. Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. On February 7, 2018, taking into consideration the pending NRG South Central acquisition, Moody’s placed Cleco Holdings Baa3 credit rating on review for downgrade and affirmed Cleco Power at A3 (stable). Also on February 7, 2018, S&P affirmed Cleco Holdings’ and Cleco Power’s credit ratings at BBB- (stable) and BBB+ (stable), respectively. On April 7, 2018, Moody’s published a credit rating update that resulted in no change to the credit ratings or outlooks of Cleco Holdings or Cleco Power. If Cleco Holdings’ or Cleco Power’s credit ratings were to be downgraded by Moody’s or S&P, Cleco Holdings and/or Cleco Power would be required to pay additional fees and incur higher interest rates for borrowings under their respective credit facilities. 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 is a participant in the MISO market. Energy prices in the MISO market are based on LMP, which includes a component directly related to congestion on the transmission system. Pricing zones with greater transmission congestion may have a higher LMP. Physical transmission constraints present in the MISO market could increase energy costs within Cleco Power’s pricing zones. Cleco Power uses FTRs to mitigate transmission congestion price risks. Changes to anticipated transmission paths may result in an unexpected increase in energy costs to Cleco Power.

Affiliate Transactions

Affiliate Transactions	3 Months Ended
	Mar. 31, 2018
Related Party Transactions [Abstract]
Affiliate Transactions	Note 13 — Affiliate Transactions Cleco Power has balances that are payable to or due from its affiliates. The following table is a summary of those balances: AT MAR. 31, 2018 AT DEC. 31, 2017 (THOUSANDS) ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE Cleco Holdings $ 90 $ 325 $ 743 $ 113 Support Group 1,221 9,644 608 8,582 Other (1) — — 4 2 Total $ 1,311 $ 9,969 $ 1,355 $ 8,697 (1) Represents Attala and Perryville.

Intangible Assets

Intangible Assets	3 Months Ended
	Mar. 31, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Intangible Assets	Note 14 — Intangible Assets During 2008, Cleco Katrina/Rita acquired a $177.5 million intangible asset which includes $176.0 million for the right to bill and collect storm recovery charges from customers of Cleco Power and $1.5 million of financing costs. The intangible asset’s expected amortization expense is based on the estimated collections from Cleco Power’s customers. At the end of its life, the asset will have no residual value. At the date of the Merger, the gross balance of the Cleco Katrina/Rita intangible asset for Cleco was adjusted to be net of accumulated amortization, as no accumulated amortization existed on the date of the Merger. During the three months ended March 31, 2018, and 2017, Cleco Katrina/Rita recognized amortization expense of $4.5 million and $3.5 million , respectively, based on actual collections. As a result of the Merger, fair value adjustments were recorded on Cleco’s Consolidated Balance Sheet for the valuation of the Cleco trade name and long-term wholesale power supply agreements. At the end of their life, these intangible assets will have no residual value. The trade name intangible asset is being amortized over its estimated economic useful life of 20 years . During the three months ended March 31, 2018, and 2017, Cleco recognized amortization expense of less that $0.1 million on the trade name intangible asset. The intangible assets related to the power supply agreements are being amortized over the remaining life of each applicable contract ranging between 5 years and 17 years . During the three months ended March 31, 2018, and 2017, Cleco recognized a reduction of revenue of $2.4 million , and $3.5 million , respectively, on the intangible assets for the power supply agreements. The following tables summarize the balances for intangible assets subject to amortization for Cleco and Cleco Power as of March 31, 2018, and December 31, 2017: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 70,594 $ 70,594 Power supply agreements 85,104 85,104 Trade name 5,100 5,100 Gross carrying amount 160,798 160,798 Accumulated amortization (52,917 ) (45,948 ) Net intangible assets subject to amortization $ 107,881 $ 114,850 Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 177,537 $ 177,537 Accumulated amortization (140,321 ) (135,836 ) Net intangible assets subject to amortization $ 37,216 $ 41,701

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	3 Months Ended
	Mar. 31, 2018
Equity [Abstract]
Accumulated Other Comprehensive Loss	Note 15 — 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 losses. Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (2,921 ) $ — $ (2,921 ) Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net loss 43 — 43 Net current-period other comprehensive income 43 — 43 Balances, Mar. 31, 2018 $ (2,878 ) $ — $ (2,878 ) FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ 1,500 $ — $ 1,500 Other comprehensive loss before reclassifications Postretirement benefits adjustment during the period (2,065 ) — (2,065 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net gain (126 ) — (126 ) Net current-period other comprehensive loss (2,191 ) — (2,191 ) Balances, Mar. 31, 2017 $ (691 ) $ — $ (691 ) Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (8,377 ) $ (5,306 ) $ (13,683 ) Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net loss 233 — 233 Reclassification of net loss to interest charges — 64 64 Net current-period other comprehensive income 233 64 297 Balances, Mar. 31, 2018 $ (8,144 ) $ (5,242 ) $ (13,386 ) FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (7,905 ) $ (5,517 ) $ (13,422 ) Other comprehensive income before reclassifications Postretirement benefit adjustments during the period (584 ) — (584 ) Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net loss 164 — 164 Reclassification of net loss to interest charges — 53 53 Net current-period other comprehensive (loss) income (420 ) 53 (367 ) Balances, Mar. 31, 2017 $ (8,325 ) $ (5,464 ) $ (13,789 )

Plan of Acquisition Plan of Acq

Plan of Acquisition Plan of Acquisition	3 Months Ended
	Mar. 31, 2018
Business Combinations [Abstract]
Plan of Acquisition	Note 16 — Plan of Acquisition On February 6, 2018, Cleco Cajun entered into the Purchase and Sale Agreement with NRG Energy and NRG South Central. Pursuant to the terms of the Purchase and Sale Agreement, Cleco Cajun agreed to acquire from NRG Energy all of the outstanding membership interests in NRG South Central, which indirectly owns (i) a 176 -MW natural-gas-fired generating station located in Sterlington, Louisiana, (ii) a 220 -MW natural-gas-fired facility and a 210 -MW natural-gas-fired peaking facility both located in Jarreau, Louisiana, (iii) a 580 -MW coal-fired generating facility, a 540 -MW natural-gas-fired generating station, and 58% of a 588 -MW coal-fired generating station all located in New Roads, Louisiana, (iv) 225 MW of a 300 -MW natural-gas-fired peaking facility located in Jennings, Louisiana, and (v) a 1,263 -MW natural-gas-fired generating station located in Deweyville, Texas (the Cottonwood Plant), for approximately $1.0 billion , subject to customary working capital and other adjustments (the NRG Acquisition). Cleco expects to fund the NRG Acquisition with proceeds from the Debt Financing (as defined below), equity contributions, and cash on hand. The transaction remains subject to customary closing conditions, including receipt of required regulatory approvals, including approvals by FERC, the LPSC, the Committee on Foreign Investment in the United States, MISO, the Public Utility Commission of Texas, and the Federal Communications Commission. On February 27, 2018, Cleco filed a joint application seeking approval of the transaction with FERC. On March 27, 2018, Cleco filed an application with the Committee on Foreign Investment in the United States seeking approval of the transaction. On April 4, 2018, Cleco filed an application with the LPSC seeking approval of the transaction. Also on April 4, 2018, the Federal Trade Commission granted early termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976. On April 13, 2018, Cleco filed an application with MISO and the Public Utility Commission of Texas seeking approval of the transaction. On April 23, 2018, Cleco received its first set of data requests from the LPSC staff for the LPSC application. Responses are due by May 8, 2018. Cleco Cajun, NRG Energy, and NRG South Central have each made customary representations, warranties and covenants in the Purchase and Sale Agreement, which includes customary indemnification provisions. Cleco Holdings has agreed to guarantee the obligations of Cleco Cajun, subject to certain limitations. In addition, the closing is conditioned upon the execution and delivery of a lease agreement between Cottonwood Energy and a special-purpose entity that is a subsidiary of NRG Energy pursuant to which NRG Energy will lease back the Cottonwood Plant and could operate it until May 2025. Upon closing, Cottonwood Energy will become a subsidiary of Cleco Cajun. The Purchase and Sale Agreement also contains certain customary termination rights for both Cleco Cajun and NRG Energy, including a termination right for each if the closing does not occur by February 6, 2019. Management expects the transaction to close before the end of 2018. In connection with the Purchase and Sale Agreement, Cleco Holdings entered into a debt commitment letter, dated as of February 6, 2018, with Mizuho Bank, Ltd. (Mizuho), Credit Agricole Corporate and Investment Bank (CA-CIB) and The Bank of Nova Scotia (Scotiabank), pursuant to which Mizuho, CA-CIB, and Scotiabank have committed to provide (a) an acquisition loan facility in the aggregate principal amount of up to $300.0 million (the Acquisition Loan Facility), (b) a term loan facility in the aggregate principal amount of up to $300.0 million (the Term Loan Facility), and (c) an incremental revolving facility under Cleco Holding’s existing bank credit agreement with availability of $75.0 million (and together with the Acquisition Loan Facility and the Term Loan Facility, the Debt Financing). The Debt Financing is subject to various conditions, including the execution of definitive documentation and other customary closing conditions.

Summary of Significant Accoun26

Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2018
Accounting Policies [Abstract]
Principles of Consolidation	The accompanying Condensed Consolidated Financial Statements of Cleco include the accounts of Cleco Holdings 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 the 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 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 year ended December 31, 2017. These Condensed Consolidated Financial Statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly state the financial position and results of operations of Cleco and Cleco Power. Amounts reported in Cleco and Cleco Power’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, discrete income tax items, and other factors. In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates. For information on recent authoritative guidance and its effect on financial results, see Note 3 — “Recent Authoritative Guidance.”
Restricted Cash and Cash Equivalents	Cleco Katrina/Rita has the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash is collected, it is restricted for payment of administration fees, interest, and principal on storm recovery bonds. 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.
Fair Value Measurements and Disclosures	Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes. Cleco utilizes different valuation techniques for fair value calculations. In order to measure the fair value for Level 1 assets and liabilities, Cleco obtains the closing price from published indices in active markets for the various instruments and multiplies this price by the appropriate number of instruments held. Cleco’s Level 2 fair values are determined by obtaining the closing price of similar assets and liabilities from published indices in active markets and then discounting the price to the current period using a U.S. Treasury published interest rate as a proxy for a risk-free rate of return. Level 3 fair values occur in situations in which there is little, if any, market activity for the asset or liability at the measurement date. Cleco’s Level 3 assets and liabilities are valued using RTO auction prices. 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.
Risk Management	Cleco Power purchases FTRs in auctions facilitated by MISO. The majority of its FTRs are purchased in annual auctions during the second quarter, but Cleco Power may purchase additional FTRs in monthly auctions. FTRs are derivative instruments which represent economic hedges of future congestion charges that will be incurred in serving Cleco Power’s customer load. FTRs are not designated as hedging instruments for accounting purposes. Cleco Power records FTRs at their estimated fair value when purchased. Each accounting period, Cleco Power adjusts the carrying value of FTRs to their estimated fair value based on the most recent MISO FTR auction prices. Unrealized gains or losses on FTRs held by Cleco Power are included in Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheets. Realized gains or losses on settled FTRs are recorded in Fuel used for electric generation on Cleco Power’s Condensed Consolidated Statements of Income. Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes in value arising from changes in interest rates and the commodity market prices of power, FTRs, and natural gas in the industry on different energy exchanges. Cleco’s Energy Market Risk Management Policy authorizes the use of various derivative instruments, including exchange traded futures and option contracts, forward purchase and sales contracts, and swap transactions to reduce exposure to fluctuations in the price of power, FTRs, and natural gas. Cleco evaluates derivatives and hedging activities to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market. Cleco Power may also enter into risk mitigating positions that would not meet the requirements of a normal-purchase, normal-sale transaction in order to attempt to mitigate the volatility in customer fuel costs. These positions would be marked-to-market with the resulting gain or loss recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets as a component of energy risk management assets or liabilities. Such gain or loss would be deferred as a component of deferred fuel assets or liabilities in accordance with regulatory policy. When these positions close, actual gains or losses would be included in the FAC and reflected on customers’ bills as a component of the fuel charge. Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, aggregate counterparty credit exposure, and aggregate counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits, or letters of credit from counterparties or their affiliates, as deemed necessary. Cleco Power has agreements in place with various counterparties that authorize the netting of financial buys and sells and contract payments to mitigate credit risk for transactions entered into for risk management purposes. Cleco and Cleco Power may enter into contracts to mitigate the volatility in interest rate risk. These contracts include, but are not limited to, interest rate swaps and treasury rate locks.
Revenue Recognition	Cleco adopted the accounting guidance for revenue recognition and all related amendments on January 1, 2018, using the modified retrospective method. The guidance affects entities that enter into contracts for the transfer of nonfinancial assets unless those contracts are within the scope of other standards. The core principle of this guidance is that an entity should recognize revenue to depict the transfer of promised goods or services to customers in an amount that reflects the consideration to which the entity expects to be entitled in exchange for those goods or services. Application of the new revenue standard did not result in a cumulative effect adjustment to the opening balance of retained earnings. The comparative information has not been restated and continues to be reported under the accounting standards in effect for those periods. The impact of the adoption of the new standard is not material to the results of operations, financial condition, or cash flows of the Registrants.
Recent Authoritative Guidance	The Registrants adopted, or will adopt, the recent authoritative guidance listed below on their respective effective dates. In February 2016, FASB amended the guidance to account for leases. This guidance is intended to increase transparency and comparability among organizations by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The adoption of this guidance is effective for fiscal years beginning after December 15, 2018, including interim periods within those years. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes practical expedients that may be elected by entities. Management expects to elect the practical expedients which permit the Registrants to retain their current lease assessment and classifications for existing leases at the effective date and to not apply the new guidance to land easements that exist or expire before the effective date. Management is currently working through an adoption plan which includes the evaluation of lease contracts, new business processes, including changes to current recordkeeping systems, and the need for additional internal controls. Other than an expected increase in assets and liabilities, the full impact of the amended guidance has not been determined. Management will continue to evaluate the impact of this guidance, including any additional clarifying amendments issued during implementation. The amended guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants. In November 2016, FASB amended guidance for certain cash flow issues. The amended guidance requires that a statement of cash flows explain the change during the period in the total of cash, cash equivalents, and amounts generally described as restricted cash. Therefore, amounts generally described as restricted cash and cash equivalents should be included with cash and cash equivalents when reconciling the beginning-of-period and end-of-period total amounts shown on the statement of cash flows. The adoption of this guidance was effective for fiscal years beginning after December 15, 2017, including interim periods within those years. This amendment was applied using a retrospective transition method to each period presented. This guidance impacted the presentation of the cash flows statement, but did not have an impact on the results of operations or financial condition of the Registrants. The following tables summarize the changes in the presentation of the Condensed Consolidated Statements of Cash Flows for Cleco and Cleco Power: Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Transfer of cash from restricted accounts, net $ 8,790 $ — Net cash used in investing activities $ (38,112 ) $ (46,902 ) Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents $ (1,558 ) $ (10,348 ) Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period $ 23,077 $ 69,571 Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period $ 21,519 $ 59,223 Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Transfer of cash from restricted accounts, net $ 8,790 $ — Net cash used in investing activities $ (36,762 ) $ (45,552 ) Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents $ (318 ) $ (9,108 ) Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period $ 21,482 $ 67,955 Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period $ 21,164 $ 58,847 In March 2017, FASB amended guidance related to defined benefit pension and other postretirement benefit plans. The new amendment requires an entity to present service cost in the same line item as other current employee compensation costs and to present the remaining components of net benefit cost in a separate line item outside of operating items. The amendment also allows only the service cost component of net benefit cost to be eligible for capitalization within property, plant, and equipment. The non-service costs will continue to be capitalized and recovered from ratepayers as approved by FERC. Beginning January 1, 2018, the non-service costs capitalized for ratemaking purposes were reflected as a regulatory asset or liability for GAAP. The adoption of this guidance was effective for annual periods beginning after December 15, 2017, including interim periods within those years. This amendment was applied retrospectively for the presentation of the service cost in the income statement while the capitalization of the service cost was applied prospectively. This guidance did not have a significant impact on the results of operations, financial condition, or cash flows of the Registrants. The following tables summarize the impact of this guidance on the Condensed Consolidated Statements of Income for Cleco and Cleco Power: Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Other operations expenses $ 31,892 $ 29,327 * Total operating expenses $ 211,703 $ 209,039 Operating income $ 38,798 $ 41,462 Other expense $ (274 ) $ (2,938 ) *Also reflects $0.1 million of Merger transaction and commitment costs that were reported in a separate line item in prior year. Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Other operations expenses $ 31,988 $ 30,264 Total operating expenses $ 209,002 $ 207,278 Operating income $ 44,700 $ 46,424 Other expense $ (274 ) $ (1,998 ) In February 2018, FASB amended guidance that permits, but does not require, companies to reclassify stranded tax effects from the TCJA from AOCI to retained earnings. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2018, including interim periods within those years. Early adoption is permitted. Management is currently evaluating this guidance and the impact it may have on the results of operations, financial condition, or cash flows of the Registrants.
Regulatory Assets and Liabilities	Cleco 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 believes these regulatory assets will be fully recoverable; however, if in the future, as a result of regulatory changes or competition, Cleco’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 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 could require discontinuance of the application of the authoritative guidance on regulated operations.
Pension Plan and Other Benefits Plan	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. Cleco recognizes expected costs of Other Benefits during the periods in which the benefits are earned. Certain Cleco officers are covered by SERP. In 2014, SERP was closed to new participants; however, with regard to current SERP participants, including former employees or their beneficiaries, all terms of SERP will continue, other than as described below. SERP is a non-qualified, non-contributory, defined benefit pension plan. Generally, benefits under the plan reflect an employee’s years of service, age at retirement and the sum of (a) the highest base salary paid out over the last five calendar years and (b) the average of the three highest cash bonuses paid during the 60 months prior to retirement. SERP benefits are reduced by retirement benefits received from any other defined benefit pension plan, supplemental executive retirement plan, or Cleco contributions under the enhanced 401(k) Plan to the extent such contributions exceed the amount the employee would have received under the terms of the original 401(k) Plan. In accordance with the SERP plan document and the Merger Agreement, four executive officers received enhanced benefits, and upon termination of employment, two of these executive officers received accelerated vesting. Another executive officer received enhanced SERP benefits, net of other postretirement benefits, as part of a separation agreement. Two executive officers’ SERP benefits were capped as of December 31, 2017, with regard to final compensation; however, adjustments will continue with regard to age and tenure with Cleco. Additionally, these executive officers had their annual bonuses set at target rather than actual awards for the years 2016 and 2017 for the average incentive award portion of their SERP benefit calculation. A third executive officer’s SERP benefit amount will be set at a specified amount based upon the year of separation. Management will review current market trends as it evaluates Cleco’s future compensation strategy. Cleco does not fund the SERP liability, but instead pays for current benefits out of the 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 the general cash available of the respective companies that employed the officer. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator. 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 401(k) Plan is voluntary, and all active Cleco employees are eligible to participate.
Uncertain Tax Positions	Cleco classifies income tax penalties as a component of other expense. Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense.
Segment Reporting	The financial results in the table below are presented on an accrual basis. Management evaluates the performance of its segment and allocates resources to it based on segment profit and the requirements to implement new strategic initiatives and projects to meet current business objectives. Material intercompany transactions occur on a regular basis. These intercompany transactions relate primarily to joint and common administrative support services.
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.
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.

Summary of Significant Accoun27

Summary of Significant Accounting Policies (Tables)	3 Months Ended
	Mar. 31, 2018
Accounting Policies [Line Items]
Restricted Cash and Cash Equivalents	Cleco and Cleco Power’s restricted cash and cash equivalents consisted of: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current Cleco Katrina/Rita’s storm recovery bonds $ 2,601 $ 8,597 Cleco Power’s charitable contributions 1,200 1,200 Cleco Power’s rate credit escrow 2,926 3,284 Total current 6,727 13,081 Non-current Diversified Lands’ mitigation escrow 21 21 Cleco Power’s future storm restoration costs 14,705 14,456 Cleco Power’s charitable contributions 3,044 3,575 Cleco Power’s rate credit escrow 1,557 2,029 Total non-current 19,327 20,081 Total restricted cash and cash equivalents $ 26,054 $ 33,162
Cleco Power
Accounting Policies [Line Items]
Restricted Cash and Cash Equivalents	Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current Cleco Katrina/Rita’s storm recovery bonds $ 2,601 $ 8,597 Charitable contributions 1,200 1,200 Rate credit escrow 2,926 3,284 Total current 6,727 13,081 Non-current Future storm restoration costs 14,705 14,456 Charitable contributions 3,044 3,575 Rate credit escrow 1,557 2,029 Total non-current 19,306 20,060 Total restricted cash and cash equivalents $ 26,033 $ 33,141

Revenue Recognition (Tables)

Revenue Recognition (Tables)	3 Months Ended
	Mar. 31, 2018
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	Operating revenue, net for the three months ended March 31, 2018, was as follows: FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL Revenue from contracts with customers Retail revenue Residential (1) $ 91,390 $ — $ — $ 91,390 Commercial (1) 66,695 — — 66,695 Industrial (1) 37,386 — — 37,386 Other retail (1) 3,801 — — 3,801 Surcharge 5,238 — — 5,238 Total retail revenue $ 204,510 $ — $ — $ 204,510 Wholesale, net (1) 43,830 (2,420 ) (2) — 41,410 Transmission 17,644 — — 17,644 Other (3) 43 1 — 44 Total revenue from contracts with customers $ 266,027 $ (2,419 ) $ — $ 263,608 Revenue unrelated to contracts with customers Affiliate $ 208 $ 15,669 $ (15,877 ) $ — Other 13,152 — — 13,152 Total revenue unrelated to contracts with customers 13,360 15,669 (15,877 ) 13,152 Operating revenue, net $ 279,387 $ 13,250 $ (15,877 ) $ 276,760 (1) Includes fuel recovery revenue. (2) Amortization of intangible assets related to wholesale power supply agreements. (3) Other revenue from contracts with customers includes $3.2 million of Teche Unit 3 SSR revenue, net of $1.9 million of reserves for capital expenditures, and other miscellaneous fee revenue, partially offset by electric customer credits.
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction	For wholesale contracts that are greater than one year, the following table discloses (1) the aggregate amount of the transaction price allocated to performance obligations that are unsatisfied (or partially unsatisfied) as of March 31, 2018, and (2) when Cleco expects to recognize this revenue: REMAINING PERFORMANCE OBLIGATIONS (THOUSANDS) Nine months ending Dec. 31, 2018 $ 7,721 Years ending Dec. 31, 2019 6,779 2020 7,068 2021 7,068 2022 6,468 Thereafter 10,210 Total wholesale contracts $ 45,314

Recent Authoritative Guidance (

Recent Authoritative Guidance (Tables)	3 Months Ended
	Mar. 31, 2018
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Schedule of New Accounting Pronouncements and Changes in Accounting Principles	The following tables summarize the changes in the presentation of the Condensed Consolidated Statements of Cash Flows for Cleco and Cleco Power: Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Transfer of cash from restricted accounts, net $ 8,790 $ — Net cash used in investing activities $ (38,112 ) $ (46,902 ) Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents $ (1,558 ) $ (10,348 ) Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period $ 23,077 $ 69,571 Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period $ 21,519 $ 59,223 Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Transfer of cash from restricted accounts, net $ 8,790 $ — Net cash used in investing activities $ (36,762 ) $ (45,552 ) Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents $ (318 ) $ (9,108 ) Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period $ 21,482 $ 67,955 Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period $ 21,164 $ 58,847 The following tables summarize the impact of this guidance on the Condensed Consolidated Statements of Income for Cleco and Cleco Power: Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Other operations expenses $ 31,892 $ 29,327 * Total operating expenses $ 211,703 $ 209,039 Operating income $ 38,798 $ 41,462 Other expense $ (274 ) $ (2,938 ) *Also reflects $0.1 million of Merger transaction and commitment costs that were reported in a separate line item in prior year. Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) AS REPORTED AS ADJUSTED Other operations expenses $ 31,988 $ 30,264 Total operating expenses $ 209,002 $ 207,278 Operating income $ 44,700 $ 46,424 Other expense $ (274 ) $ (1,998 )

Regulatory Assets and Liabili30

Regulatory Assets and Liabilities (Tables)	3 Months Ended
	Mar. 31, 2018
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Schedule of Regulatory Assets and Liabilities, Net	The following table summarizes Cleco’s net regulatory assets and liabilities: (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Total Cleco Power regulatory assets, net $ 150,794 $ 146,774 Cleco Merger adjustments (1) Fair value of long-term debt 145,033 147,145 Postretirement costs 20,878 21,375 Financing costs 8,536 8,623 Debt issuance costs 6,562 6,665 Total Cleco regulatory assets, net $ 331,803 $ 330,582 (1) Cleco regulatory assets include acquisition accounting adjustments as a result of the Merger.
Cleco Power
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Schedule of Regulatory Assets and Liabilities, Net	The following table summarizes Cleco Power’s regulatory assets and liabilities: (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Regulatory liabilities - deferred taxes, net $ (138,329 ) $ (140,426 ) Mining costs 3,186 3,823 Interest costs 4,410 4,499 AROs 2,689 2,762 Postretirement costs 139,822 142,764 Tree trimming costs 7,579 7,193 Training costs 6,513 6,552 Surcredits, net 1,195 2,173 AMI deferred revenue requirement 4,090 4,227 Emergency declarations 4,004 4,131 Production operations and maintenance expenses 7,226 8,625 AFUDC equity gross-up 71,245 71,205 Acadia Unit 1 acquisition costs 2,310 2,336 Financing costs 8,201 8,293 MISO integration costs 234 468 Coughlin transaction costs 961 968 Corporate franchise tax, net — 153 MATS costs 1,282 2,564 Non-service cost of postretirement benefits 1,037 — Other 255 484 Total regulatory assets 266,239 273,220 Corporate franchise tax, net (169 ) — Accumulated deferred fuel 23,053 13,980 Total regulatory assets, net $ 150,794 $ 146,774

Fair Value Accounting (Tables)

Fair Value Accounting (Tables)	3 Months Ended
	Mar. 31, 2018
Fair Value [Line Items]
Fair Value By Balance Sheet Grouping	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 MAR. 31, 2018 AT DEC. 31, 2017 (THOUSANDS) CARRYING VALUE* FAIR VALUE CARRYING VALUE* FAIR VALUE Long-term debt $ 2,905,222 $ 2,924,772 $ 2,866,955 $ 2,921,325 * The carrying value of long-term debt does not include deferred issuance costs of $11.3 million and $11.6 million at March 31, 2018 , and December 31, 2017 , respectively.
Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis	The following tables disclose for Cleco and Cleco Power the fair value of financial assets and liabilities measured on a recurring basis: Cleco CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE (THOUSANDS) AT MAR. 31, 2018 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) AT DEC. 31, 2017 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) Asset description Institutional money market funds $ 198,446 $ — $ 198,446 $ — $ 144,302 $ — $ 144,302 $ — FTRs 4,828 — — 4,828 7,396 — — 7,396 Total assets $ 203,274 $ — $ 198,446 $ 4,828 $ 151,698 $ — $ 144,302 $ 7,396 Liability description FTRs $ 545 $ — $ — $ 545 $ 352 $ — $ — $ 352 Total liabilities $ 545 $ — $ — $ 545 $ 352 $ — $ — $ 352
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation	The following table summarizes 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: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 Beginning balance $ 7,044 $ 7,683 Unrealized gains* 1,617 2,104 Purchases 371 275 Settlements (4,749 ) (5,644 ) Ending balance $ 4,283 $ 4,418 * Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets.
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques	The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions as of March 31, 2018 , and December 31, 2017 : FAIR VALUE VALUATION TECHNIQUE SIGNIFICANT UNOBSERVABLE INPUTS FORWARD PRICE RANGE (THOUSANDS, EXCEPT FORWARD PRICE RANGE) ASSETS LIABILITIES LOW HIGH FTRs at Mar. 31, 2018 $ 4,828 $ 545 RTO auction pricing FTR price - per MWh $ (7.21 ) $ 7.21 FTRs at Dec. 31, 2017 $ 7,396 $ 352 RTO auction pricing FTR price - per MWh $ (2.95 ) $ 6.33
Derivatives Not Designated As Hedging Instrument
Fair Value [Line Items]
Fair Value of Derivative Instruments in Statement of Financial Position	The following table presents the fair values of derivative instruments and their respective line items as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2018 , and December 31, 2017 : DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS (THOUSANDS) BALANCE SHEET LINE ITEM AT MAR. 31, 2018 AT DEC. 31, 2017 Commodity-related contracts FTRs Current Energy risk management assets $ 4,828 $ 7,396 Current Other current liabilities 545 352 Commodity-related contracts, net $ 4,283 $ 7,044
Effect of Derivatives On Consolidated Statements of Income	The following table presents the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2018 , and 2017 : AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) DERIVATIVES LINE ITEM 2018 2017 Commodity contracts FTRs (1) Electric operations $ 18,150 $ 9,163 FTRs (1) Power purchased for utility customers (5,667 ) (4,665 ) Total $ 12,483 $ 4,498 (1) For the three months ended March 31, 2018 , and 2017, unrealized gains associated with FTRs of $1.6 million and $2.1 million , respectively, were reported through Accumulated deferred fuel on
Cleco Power
Fair Value [Line Items]
Fair Value By Balance Sheet Grouping	Cleco Power AT MAR. 31, 2018 AT DEC. 31, 2017 (THOUSANDS) CARRYING VALUE* FAIR VALUE CARRYING VALUE* FAIR VALUE Long-term debt $ 1,410,188 $ 1,555,341 $ 1,369,810 $ 1,535,234 * The carrying value of long-term debt does not include deferred issuance costs of $8.9 million and $9.1 million at March 31, 2018 , and December 31, 2017 , respectively.
Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis	Cleco Power CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE (THOUSANDS) AT MAR. 31, 2018 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) AT DEC. 31, 2017 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) Asset description Institutional money market funds $ 151,225 $ — $ 151,225 $ — $ 95,681 $ — $ 95,681 $ — FTRs 4,828 — — 4,828 7,396 — — 7,396 Total assets $ 156,053 $ — $ 151,225 $ 4,828 $ 103,077 $ — $ 95,681 $ 7,396 Liability description FTRs $ 545 $ — $ — $ 545 $ 352 $ — $ — $ 352 Total liabilities $ 545 $ — $ — $ 545 $ 352 $ — $ — $ 352

Pension Plan and Employee Ben32

Pension Plan and Employee Benefits (Tables)	3 Months Ended
	Mar. 31, 2018
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit costs	Net periodic pension and Other Benefits cost for the three months ended March 31, 2018 , and 2017 were as follows: PENSION BENEFITS OTHER BENEFITS FOR THE THREE MONTHS ENDED MAR. 31, FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 2018 2017 Components of periodic benefit costs Service cost $ 2,393 $ 2,225 $ 338 $ 385 Interest cost 5,183 5,358 357 403 Expected return on plan assets (5,938 ) (6,138 ) — — Amortizations Prior period service credit (18 ) (18 ) — — Net loss (gain) 2,960 2,413 5 (3 ) Net periodic benefit cost $ 4,580 $ 3,840 $ 700 $ 785
401(k) Plan expense	Cleco’s 401(k) Plan expense for the three months ended March 31, 2018 , and 2017 , was as follows: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 401(k) Plan expense $ 2,063 $ 1,668
OTHER BENEFITS
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of current and non-current portions	The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at March 31, 2018 , and December 31, 2017 , were as follows: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current $ 4,061 $ 4,061 Non-current $ 38,684 $ 39,142
SERP Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Net periodic benefit costs	Net periodic benefit cost related to SERP for the three months ended March 31, 2018 , and 2017 , were as follows: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 Components of periodic benefit costs Service cost $ 105 $ 145 Interest cost 760 800 Amortizations Prior period service credit (35 ) (57 ) Net loss 585 419 Net periodic benefit cost 1,415 1,307 Special/contractual termination benefits — 315 Total benefit cost $ 1,415 $ 1,622
Schedule of current and non-current portions	The current and non-current portions of the SERP liability for Cleco and Cleco Power at March 31, 2018 , and December 31, 2017 , were as follows: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current $ 4,471 $ 4,471 Non-current $ 79,637 $ 79,868
Other Subsidiaries
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
401(k) Plan expense	The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three months ended March 31, 2018 , and 2017 , was as follows: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 401(k) Plan expense $ 402 $ 279
Cleco Power | OTHER BENEFITS
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of current and non-current portions	Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current $ 3,525 $ 3,525 Non-current $ 33,648 $ 34,033
Cleco Power | SERP Benefits
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Schedule of current and non-current portions	Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Current $ 929 $ 929 Non-current $ 16,560 $ 16,589

Income Taxes (Tables)

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2018
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 months ended March 31, 2018 , and 2017 : Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2018 2017 Effective tax rate 20.9 % 33.1 %
Cleco Power
Effective Income Tax Rate [Line Items]
Effective income tax rates	Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2018 2017 Effective tax rate 23.5 % 35.6 %

Disclosures about Segments (Tab

Disclosures about Segments (Tables)	3 Months Ended
	Mar. 31, 2018
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) CLECO POWER OTHER ELIMINATIONS CONSOLIDATED Revenue Electric operations $ 264,631 $ (2,420 ) $ — $ 262,211 Other operations 22,195 1 — 22,196 Electric customer credits (7,647 ) — — (7,647 ) Affiliate revenue 208 15,669 (15,877 ) — Operating revenue, net $ 279,387 $ 13,250 $ (15,877 ) $ 276,760 Depreciation and amortization $ 40,388 $ 2,119 $ — $ 42,507 Interest charges $ 17,656 $ 13,549 $ (48 ) $ 31,157 Interest income $ 641 $ 190 $ (48 ) $ 783 Federal and state income tax expense (benefit) $ 7,997 $ (5,135 ) $ — $ 2,862 Net income (loss) $ 26,004 $ (15,142 ) $ (1 ) $ 10,861 Additions to property, plant, and equipment $ 63,343 $ 790 $ — $ 64,133 Equity investment in investees $ 18,172 $ — $ — $ 18,172 Goodwill $ 1,490,797 $ — $ — $ 1,490,797 Total segment assets $ 5,722,284 $ 618,513 $ (30,816 ) $ 6,309,981 2017 (THOUSANDS) CLECO POWER OTHER ELIMINATIONS CONSOLIDATED Revenue Electric operations $ 237,553 $ (3,497 ) $ — $ 234,056 Other operations 16,365 515 — 16,880 Electric customer credits (435 ) — — (435 ) Affiliate revenue 219 14,734 (14,953 ) — Operating revenue, net $ 253,702 $ 11,752 $ (14,953 ) $ 250,501 Depreciation and amortization $ 38,758 $ 2,093 $ — $ 40,851 Interest charges $ 18,104 $ 13,681 $ (67 ) $ 31,718 Interest income $ 266 $ 113 $ (67 ) $ 312 Federal and state income tax expense (benefit) $ 9,855 $ (6,748 ) $ — $ 3,107 Net income (loss) $ 17,854 $ (11,562 ) $ — $ 6,292 Additions to property, plant, and equipment $ 46,744 $ 1,146 $ — $ 47,890 Equity investment in investees (1) $ 18,172 $ — $ — $ 18,172 Goodwill (1) $ 1,490,797 $ — $ — $ 1,490,797 Total segment assets (1) $ 5,679,538 $ 619,943 $ (21,099 ) $ 6,278,382 (1) Balances as of December 31, 2017

Variable Interest Entities (Tab

Variable Interest Entities (Tables) - Cleco Power	3 Months Ended
	Mar. 31, 2018
Variable Interest Entity [Line Items]
Equity Method Investments	The following table contains summarized financial information for Oxbow: FOR THE THREE MONTHS ENDED MAR. 31, (THOUSANDS) 2018 2017 Operating revenue $ 863 $ 1,073 Operating expenses 863 1,073 Income before taxes $ — $ — The following table presents the components of Cleco Power’s equity investment in Oxbow: INCEPTION TO DATE (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Purchase price $ 12,873 $ 12,873 Cash contributions 6,399 6,399 Dividends (1,100 ) (1,100 ) Total equity investment in investee $ 18,172 $ 18,172
Comparison of Investee's 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 MAR. 31, 2018 AT DEC. 31, 2017 Oxbow’s net assets/liabilities $ 36,345 $ 36,345 Cleco Power’s 50% equity $ 18,172 $ 18,172 Cleco Power’s maximum exposure to loss $ 18,172 $ 18,172

Affiliate Transactions (Tables)

Affiliate Transactions (Tables)	3 Months Ended
	Mar. 31, 2018
Cleco Power
Related Party Transaction [Line Items]
Schedule of Related Party Transactions	Cleco Power has balances that are payable to or due from its affiliates. The following table is a summary of those balances: AT MAR. 31, 2018 AT DEC. 31, 2017 (THOUSANDS) ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE Cleco Holdings $ 90 $ 325 $ 743 $ 113 Support Group 1,221 9,644 608 8,582 Other (1) — — 4 2 Total $ 1,311 $ 9,969 $ 1,355 $ 8,697 (1) Represents Attala and Perryville.

Intangible Assets (Tables)

Intangible Assets (Tables)	3 Months Ended
	Mar. 31, 2018
Goodwill and Intangible Assets Disclosure [Abstract]
Schedule of Finite-Lived Intangible Assets	The following tables summarize the balances for intangible assets subject to amortization for Cleco and Cleco Power as of March 31, 2018, and December 31, 2017: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 70,594 $ 70,594 Power supply agreements 85,104 85,104 Trade name 5,100 5,100 Gross carrying amount 160,798 160,798 Accumulated amortization (52,917 ) (45,948 ) Net intangible assets subject to amortization $ 107,881 $ 114,850 Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 177,537 $ 177,537 Accumulated amortization (140,321 ) (135,836 ) Net intangible assets subject to amortization $ 37,216 $ 41,701
Schedule of Indefinite-Lived Intangible Assets	The following tables summarize the balances for intangible assets subject to amortization for Cleco and Cleco Power as of March 31, 2018, and December 31, 2017: Cleco (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 70,594 $ 70,594 Power supply agreements 85,104 85,104 Trade name 5,100 5,100 Gross carrying amount 160,798 160,798 Accumulated amortization (52,917 ) (45,948 ) Net intangible assets subject to amortization $ 107,881 $ 114,850 Cleco Power (THOUSANDS) AT MAR. 31, 2018 AT DEC. 31, 2017 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 177,537 $ 177,537 Accumulated amortization (140,321 ) (135,836 ) Net intangible assets subject to amortization $ 37,216 $ 41,701

Accumulated Other Comprehensi38

Accumulated Other Comprehensive Loss (Tables)	3 Months Ended
	Mar. 31, 2018
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 losses. Cleco FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (2,921 ) $ — $ (2,921 ) Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net loss 43 — 43 Net current-period other comprehensive income 43 — 43 Balances, Mar. 31, 2018 $ (2,878 ) $ — $ (2,878 ) FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ 1,500 $ — $ 1,500 Other comprehensive loss before reclassifications Postretirement benefits adjustment during the period (2,065 ) — (2,065 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net gain (126 ) — (126 ) Net current-period other comprehensive loss (2,191 ) — (2,191 ) Balances, Mar. 31, 2017 $ (691 ) $ — $ (691 ) Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (8,377 ) $ (5,306 ) $ (13,683 ) Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net loss 233 — 233 Reclassification of net loss to interest charges — 64 64 Net current-period other comprehensive income 233 64 297 Balances, Mar. 31, 2018 $ (8,144 ) $ (5,242 ) $ (13,386 )
Cleco Power
Accumulated Other Comprehensive Loss [Line Items]
Schedule of Accumulated Other Comprehensive Income (Loss)	Cleco Power FOR THE THREE MONTHS ENDED MAR. 31, 2018 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (8,377 ) $ (5,306 ) $ (13,683 ) Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net loss 233 — 233 Reclassification of net loss to interest charges — 64 64 Net current-period other comprehensive income 233 64 297 Balances, Mar. 31, 2018 $ (8,144 ) $ (5,242 ) $ (13,386 ) FOR THE THREE MONTHS ENDED MAR. 31, 2017 (THOUSANDS) POSTRETIREMENT NET LOSS TOTAL AOCI Balances, beginning of period $ (7,905 ) $ (5,517 ) $ (13,422 ) Other comprehensive income before reclassifications Postretirement benefit adjustments during the period (584 ) — (584 ) Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net loss 164 — 164 Reclassification of net loss to interest charges — 53 53 Net current-period other comprehensive (loss) income (420 ) 53 (367 ) Balances, Mar. 31, 2017 $ (8,325 ) $ (5,464 ) $ (13,789 )

Summary of Significant Accoun39

Summary of Significant Accounting Policies, Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Restricted Cash and Cash Equivalents Items [Line Items]
Current	$ 6,727	$ 13,081
Non-current	19,327	20,081
Total restricted cash and cash equivalents	26,054	33,162
Cleco Katrina/Rita’s storm recovery bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Current	2,601	8,597
Charitable contributions
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,200	1,200
Non-current	3,044	3,575
Rate credit escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Current	2,926	3,284
Non-current	1,557	2,029
Diversified Lands’ mitigation escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Non-current	21	21
Future storm restoration costs
Restricted Cash and Cash Equivalents Items [Line Items]
Non-current	14,705	14,456
Cleco Katrina/Rita Bond Principal Payments
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (decrease) in restricted cash	(9,700)
Cleco Katrina/Rita Bond Interest Payments [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (decrease) in restricted cash	(1,400)
Cleco Katrina/Rita storm recovery collections, net of administration fees
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (decrease) in restricted cash	5,100
Cleco Power
Restricted Cash and Cash Equivalents Items [Line Items]
Current	6,727	13,081
Non-current	19,306	20,060
Total restricted cash and cash equivalents	26,033	33,141
Cleco Power | Cleco Katrina/Rita’s storm recovery bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Current	2,601	8,597
Cleco Power | Charitable contributions
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,200	1,200
Non-current	3,044	3,575
Cleco Power | Rate credit escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Current	2,926	3,284
Non-current	1,557	$ 2,029
Cleco Power | Future storm restoration costs
Restricted Cash and Cash Equivalents Items [Line Items]
Non-current	$ 14,705

Summary of Significant Accoun40

Summary of Significant Accounting Policies, Risk Management (Details) - derivative	3 Months Ended
	Mar. 31, 2018	Dec. 31, 2017
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Long-term natural gas hedging pilot program, minimum period for gas price stability	5 years
Cleco Power | Open Natural Gas Positions
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk	0	0

Revenue Recognition - Narrative

Revenue Recognition - Narrative (Details)	3 Months Ended
	Mar. 31, 2018USD ($)
Revenue from Contract with Customer [Abstract]
Payment terms	20 years
Contract with customer, liability	$ 0

Revenue Recognition - Disaggreg

Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 263,608
Affiliate revenue	0	$ 0
Other operations	13,152
Revenue unrelated to contracts with customers	13,152
Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	204,510
Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	91,390
Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	66,695
Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	37,386
Other retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3,801
Surcharge
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	5,238
Wholesale, net
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	41,410
Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	17,644
Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	44
Cleco Power | Other
Disaggregation of Revenue [Line Items]
Reserve for capital expenditures	1,900
Operating Segments | Cleco Power
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	266,027
Affiliate revenue	208	219
Other operations	13,152
Revenue unrelated to contracts with customers	13,360
Operating Segments | Cleco Power | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	204,510
Operating Segments | Cleco Power | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	91,390
Operating Segments | Cleco Power | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	66,695
Operating Segments | Cleco Power | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	37,386
Operating Segments | Cleco Power | Other retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3,801
Operating Segments | Cleco Power | Surcharge
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	5,238
Operating Segments | Cleco Power | Wholesale, net
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	43,830
Operating Segments | Cleco Power | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	17,644
Operating Segments | Cleco Power | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	43
Operating Segments | OTHER
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	(2,419)
Affiliate revenue	15,669	14,734
Other operations	0
Revenue unrelated to contracts with customers	15,669
Operating Segments | OTHER | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Operating Segments | OTHER | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Operating Segments | OTHER | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Operating Segments | OTHER | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Operating Segments | OTHER | Other retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Operating Segments | OTHER | Surcharge
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Operating Segments | OTHER | Wholesale, net
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	(2,420)
Operating Segments | OTHER | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Operating Segments | OTHER | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	1
ELIMINATIONS
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Affiliate revenue	(15,877)	(14,953)
Other operations	0
Revenue unrelated to contracts with customers	(15,877)
ELIMINATIONS | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
ELIMINATIONS | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
ELIMINATIONS | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
ELIMINATIONS | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
ELIMINATIONS | Other retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
ELIMINATIONS | Surcharge
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
ELIMINATIONS | Wholesale, net
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
ELIMINATIONS | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
ELIMINATIONS | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0
Cleco Power
Disaggregation of Revenue [Line Items]
Affiliate revenue	208	$ 219
SSR | Cleco Power | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 3,200

Revenue Recognition - Remaining

Revenue Recognition - Remaining Performance Obligations (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 7,721
Revenue, remaining performance obligation, expected timing of satisfaction, period	9 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2019-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 6,779
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2020-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 7,068
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2021-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 7,068
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 6,468
Revenue, remaining performance obligation, expected timing of satisfaction, period	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 45,314
Revenue, remaining performance obligation, expected timing of satisfaction, period

Recent Authoritative Guidance -

Recent Authoritative Guidance - ASU 2016-18 (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018		Mar. 31, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net cash used in investing activities	$ (57,748)		$ (46,902)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	50,360		(10,348)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	152,202	[1]	69,571
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	202,562	[2]	59,223
Accounting Standards Update 2016-18
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Transfer of cash from restricted accounts, net			0
Net cash used in investing activities			(46,902)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents			(10,348)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period			69,571
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period			59,223
AS REPORTED | Accounting Standards Update 2016-18
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Transfer of cash from restricted accounts, net			8,790
Net cash used in investing activities			(38,112)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents			(1,558)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period			23,077
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period			21,519
Cleco Power
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net cash used in investing activities	(59,733)		(45,552)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	51,258		(9,108)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	102,957	[3]	67,955
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	$ 154,215	[4]	58,847
Cleco Power | Accounting Standards Update 2016-18
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Transfer of cash from restricted accounts, net			0
Net cash used in investing activities			(45,552)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents			(9,108)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period			67,955
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period			58,847
Cleco Power | AS REPORTED | Accounting Standards Update 2016-18
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Transfer of cash from restricted accounts, net			8,790
Net cash used in investing activities			(36,762)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents			(318)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period			21,482
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period			$ 21,164
[1]	Includes cash and cash equivalents are $119,040, current restricted cash and cash equivalents are $13,081, non-current restricted cash and cash equivalents are $20,081.
[2]	Includes cash and cash equivalents are $176,508, current restricted cash and cash equivalents are $6,727, non-current restricted cash and cash equivalents are $19,327.
[3]	Includes cash and cash equivalents are $69,816, current restricted cash and cash equivalents are $13,081, non-current restricted cash and cash equivalents are $20,060.
[4]	Includes cash and cash equivalents are $128,182, current restricted cash and cash equivalents are $6,727, non-current restricted cash and cash equivalents are $19,306.

Recent Authoritative Guidance45

Recent Authoritative Guidance - ASU 2017-07 (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations	$ 27,967	$ 29,327
Total operating expenses	232,026	209,039
Operating income	44,734	41,462
Other expense	(3,554)	(2,938)
Accounting Standards Update 2017-07
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations		29,327
Total operating expenses		209,039
Operating income		41,462
Other expense		2,938
Payments for merger related costs	100
Accounting Standards Update 2017-07 | AS REPORTED
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations		31,892
Total operating expenses		211,703
Operating income		38,798
Other expense		(274)
Cleco Power
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations	27,307	30,264
Total operating expenses	228,866	207,278
Operating income	50,521	46,424
Other expense	$ (2,608)	(1,998)
Cleco Power | Accounting Standards Update 2017-07
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations		30,264
Total operating expenses		207,278
Operating income		46,424
Other expense		1,998
Cleco Power | Accounting Standards Update 2017-07 | AS REPORTED
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations		31,988
Total operating expenses		209,002
Operating income		44,700
Other expense		$ (274)

Regulatory Assets and Liabili46

Regulatory Assets and Liabilities, Summary of Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Total regulatory assets, net	$ 331,803	$ 330,582
Cleco Power
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	266,239	273,220
Total regulatory assets, net	150,794	146,774
Cleco Power | Mining costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	3,186	3,823
Cleco Power | Interest costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,410	4,499
Cleco Power | AROs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,689	2,762
Cleco Power | Postretirement costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	139,822	142,764
Cleco Power | Tree trimming costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	7,579	7,193
Cleco Power | Training costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	6,513	6,552
Cleco Power | Surcredits, net
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	1,195	2,173
Cleco Power | AMI deferred revenue requirement
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,090	4,227
Cleco Power | Emergency declarations
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,004	4,131
Cleco Power | Production operations and maintenance expenses
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	7,226	8,625
Cleco Power | AFUDC equity gross-up
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	71,245	71,205
Cleco Power | Acquisition/ transaction costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,310	2,336
Cleco Power | Acquisition/ transaction costs | Coughlin transaction costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	961	968
Cleco Power | Financing costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,201	8,293
Cleco Power | MISO integration costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	234	468
Cleco Power | Corporate franchise tax, net
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	0	153
Cleco Power | MATS costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	1,282	2,564
Cleco Power | Non-service cost of postretirement benefits
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	1,037	0
Cleco Power | Other
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	255	484
Cleco Power | Accumulated deferred fuel
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	23,053	13,980
Cleco Holdings | Postretirement costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	20,878	21,375
Cleco Holdings | Financing costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,536	8,623
Cleco Holdings | Fair value of long-term debt
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	145,033	147,145
Cleco Holdings | Debt issuance costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	6,562	6,665
Regulatory liabilities - deferred taxes, net | Cleco Power
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory liabilities	(138,329)	(140,426)
Corporate franchise tax, net | Cleco Power
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory liabilities	$ (169)	$ 0

Fair Value Accounting, Carrying

Fair Value Accounting, Carrying Value and Estimated Fair Value (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Financial instruments not marked-to-market [Abstract]
Deferred debt issuance costs not included in the carrying value of long-term debt	$ 11,300	$ 11,600
Carrying Value
Financial instruments not marked-to-market [Abstract]
Long-term debt	2,905,222	2,866,955
FAIR VALUE
Financial instruments not marked-to-market [Abstract]
Long-term debt	2,924,772	2,921,325
Cleco Power
Financial instruments not marked-to-market [Abstract]
Deferred debt issuance costs not included in the carrying value of long-term debt	8,900	9,100
Cleco Power | Carrying Value
Financial instruments not marked-to-market [Abstract]
Long-term debt	1,410,188	1,369,810
Cleco Power | FAIR VALUE
Financial instruments not marked-to-market [Abstract]
Long-term debt	$ 1,555,341	$ 1,535,234

Fair Value Accounting, Fair Val

Fair Value Accounting, Fair Value Measurements and Disclosures(Details)	3 Months Ended
	Mar. 31, 2018USD ($)$ / MW	Mar. 31, 2017USD ($)	Dec. 31, 2017USD ($)$ / MW
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
FTR forward price - per MWh, low | $ / MW	(7.21)		(2.95)
FTR forward price - per MWh, high | $ / MW	7.21		6.33
Fair value, concentration of risk, amount of money market funds in cash and cash equivalents	$ 172,500,000		$ 111,100,000
Fair value, assets and liabilities, transfers between levels, amount	0		0
Restricted Cash and Cash Equivalents, Current
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair value, concentration of risk, amount of money market funds in institutional money market funds	6,700,000		13,100,000
Restricted Cash and Cash Equivalents, Noncurrent
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair value, concentration of risk, amount of money market funds in institutional money market funds	19,200,000		20,100,000
Measured On A Recurring Basis
Asset description
Institutional money market funds	198,446,000		144,302,000
FTRs	4,828,000		7,396,000
Total assets	203,274,000		151,698,000
Liability description
FTRs	545,000		352,000
Total liabilities	545,000		352,000
Price Risk Derivative
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	7,044,000	$ 7,683,000
Unrealized gains	1,617,000	2,104,000
Purchases	371,000	275,000
Settlements	(4,749,000)	(5,644,000)
Ending balance	4,283,000	$ 4,418,000
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | Measured On A Recurring Basis
Asset description
Institutional money market funds	0		0
FTRs	0		0
Total assets	0		0
Liability description
FTRs	0		0
Total liabilities	0		0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | Measured On A Recurring Basis
Asset description
Institutional money market funds	198,446,000		144,302,000
FTRs	0		0
Total assets	198,446,000		144,302,000
Liability description
FTRs	0		0
Total liabilities	0		0
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | Measured On A Recurring Basis
Asset description
Institutional money market funds	0		0
FTRs	4,828,000		7,396,000
Total assets	4,828,000		7,396,000
Liability description
FTRs	545,000		352,000
Total liabilities	545,000		352,000
Cleco Power
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair value, concentration of risk, amount of money market funds in cash and cash equivalents	125,300,000		62,500,000
Cleco Power | Restricted Cash and Cash Equivalents, Current
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair value, concentration of risk, amount of money market funds in institutional money market funds	6,700,000		13,100,000
Cleco Power | Restricted Cash and Cash Equivalents, Noncurrent
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair value, concentration of risk, amount of money market funds in institutional money market funds	19,200,000		20,100,000
Cleco Power | Measured On A Recurring Basis
Asset description
Institutional money market funds	151,225,000		95,681,000
FTRs	4,828,000		7,396,000
Total assets	156,053,000		103,077,000
Liability description
FTRs	545,000		352,000
Total liabilities	545,000		352,000
Cleco Power | QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | Measured On A Recurring Basis
Asset description
Institutional money market funds	0		0
FTRs	0		0
Total assets	0		0
Liability description
FTRs	0		0
Total liabilities	0		0
Cleco Power | SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | Measured On A Recurring Basis
Asset description
Institutional money market funds	151,225,000		95,681,000
FTRs	0		0
Total assets	151,225,000		95,681,000
Liability description
FTRs	0		0
Total liabilities	0		0
Cleco Power | SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | Measured On A Recurring Basis
Asset description
Institutional money market funds	0		0
FTRs	4,828,000		7,396,000
Total assets	4,828,000		7,396,000
Liability description
FTRs	545,000		352,000
Total liabilities	$ 545,000		$ 352,000

Fair Value Accounting, Commodit

Fair Value Accounting, Commodity Contracts (Details) $ in Thousands, MWh in Millions	3 Months Ended
	Mar. 31, 2018USD ($)MWh	Mar. 31, 2017USD ($)MWh	Dec. 31, 2017USD ($)
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument
FTRs, at Fair Value, Net [Abstract]
Commodity-related contracts, net	$ 4,283		$ 7,044
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income	12,483	$ 4,498
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Energy risk management assets
FTRs, at Fair Value, Net [Abstract]
FTRs in energy risk management assets	4,828		7,396
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Other current liabilities
FTRs, at Fair Value, Net [Abstract]
FTRs in Energy risk management liabilities	545		$ 352
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Accumulated deferred fuel
FTRs [Abstract]
Unrealized gains (losses) associated with FTRs not recognized in income on derivatives	1,600	2,100
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Electric operations
FTRs [Abstract]
Gain on FTRs recognized in income	18,150	9,163
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Power purchased for utility customers
FTRs [Abstract]
Loss on FTRs recognized in income	$ (5,667)	$ (4,665)
Cleco Power
FTRs [Abstract]
Volume of FTRs Held (MWh) | MWh	3.8	9

Debt - (Details)

Debt - (Details) - Senior Notes	Mar. 26, 2018USD ($)	Dec. 18, 2017USD ($)tranche
Note Purchase Agreement
Debt Instrument [Line Items]
Debt amount		$ 175,000,000
Number of issuance tranches | tranche		2
Note Purchase Agreement - 2.94%
Debt Instrument [Line Items]
Debt amount		$ 25,000,000
Interest rate, stated percentage (in hundredths)		2.94%
Note Purchase Agreement - 3.08%
Debt Instrument [Line Items]
Debt amount		$ 100,000,000
Interest rate, stated percentage (in hundredths)		3.08%
Note Purchase Agreement - 3.17%
Debt Instrument [Line Items]
Debt amount	$ 50,000,000
Interest rate, stated percentage (in hundredths)	3.17%

Pension Plan and Employee Ben51

Pension Plan and Employee Benefits, Pension Plan and Other Benefits Plan (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
PENSION BENEFITS
Components of periodic benefit costs
Service cost	$ 2,393	$ 2,225
Interest cost	5,183	5,358
Expected return on plan assets	(5,938)	(6,138)
Prior period service credit	(18)	(18)
Net loss (gain)	2,960	2,413
Net periodic benefit cost	4,580	3,840
OTHER BENEFITS
Components of periodic benefit costs
Service cost	338	385
Interest cost	357	403
Expected return on plan assets	0	0
Prior period service credit	0	0
Net loss (gain)	5	(3)
Net periodic benefit cost	700	785
Cleco Power | OTHER BENEFITS
Components of periodic benefit costs
Net periodic benefit cost	$ 800	$ 900

Pension Plan and Employee Ben52

Pension Plan and Employee Benefits - Narrative (Details) - USD ($)	Mar. 30, 2017	Mar. 31, 2018	Mar. 31, 2017	Mar. 29, 2017
PENSION BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		$ 4,580,000	$ 3,840,000
OTHER BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		700,000	785,000
Assets held-in-trust, noncurrent		0
SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		1,415,000	1,622,000
Defined benefit plan, assumptions used calculating benefit obligation, discount rate	4.08%			4.22%
Defined benefit plan, net periodic benefit cost (credit), gain (loss) due to settlement	$ (300,000)	0	(315,000)
Cleco Power | OTHER BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		800,000	900,000
Cleco Power | SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		300,000	300,000
Other Subsidiaries | PENSION BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		$ 500,000	$ 400,000

Pension Plan and Employee Ben53

Pension Plan and Employee Benefits - Current and Non-current Portions of the Other Benefits Liability (Details) - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Non-current	$ 243,084	$ 242,135
OTHER BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Current	4,061	4,061
Non-current	38,684	39,142
SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Current	4,471	4,471
Non-current	79,637	79,868
Cleco Power
Defined Benefit Plan Disclosure [Line Items]
Non-current	174,971	173,747
Cleco Power | OTHER BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Current	3,525	3,525
Non-current	33,648	34,033
Cleco Power | SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Current	929	929
Non-current	$ 16,560	$ 16,589

Pension Plan and Employee Ben54

Pension Plan and Employee Benefits, SERP (Details) - SERP Benefits - USD ($) $ in Thousands	Mar. 30, 2017	Mar. 31, 2018	Mar. 31, 2017
Components of periodic benefit costs
Service cost		$ 105	$ 145
Interest cost		760	800
Prior period service credit		(35)	(57)
Net loss (gain)		585	419
Net periodic benefit cost		1,415	1,307
Special/contractual termination benefits	$ 300	0	315
Net periodic benefit cost		1,415	1,622
Cleco Power
Components of periodic benefit costs
Net periodic benefit cost		$ 300	$ 300

Pension Plan and Employee Ben55

Pension Plan and Employee Benefits, 401 (K) Plans (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense	$ 2,063	$ 1,668
Other Subsidiaries
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense	$ 402	$ 279

Income Taxes, Effective Tax Rat

Income Taxes, Effective Tax Rate Reconciliation (Details)	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Effective Income Tax Rate [Line Items]
Effective tax rate	20.90%	33.10%
Cleco Power
Effective Income Tax Rate [Line Items]
Effective tax rate	23.50%	35.60%

Income Taxes, Narrative (Detail

Income Taxes, Narrative (Details) - USD ($)	3 Months Ended		12 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Uncertain Tax Positions [Line Items]
Interest payable related to uncertain tax positions	$ 0		$ 0
Interest expense related to uncertain tax positions	0	$ 0
Liability for uncertain tax positions	0
Penalties	0	0
Decrease in deferred income taxes			46,300,000
Decrease in accumulated deferred income tax liability	0		394,900,000
Cleco Power
Uncertain Tax Positions [Line Items]
Interest payable related to uncertain tax positions	0		0
Interest expense related to uncertain tax positions	0	$ 0
Decrease in deferred income taxes			14,300,000
Decrease in accumulated deferred income tax liability	$ 0		$ 362,900,000

Disclosures about Segments (Det

Disclosures about Segments (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2018USD ($)entity	Mar. 31, 2017USD ($)	Dec. 31, 2017USD ($)
Segment Reporting Information [Line Items]
Number of transmission interconnection facility subsidiaries | entity	2
Revenue [Abstract]
Electric operations	$ 262,211	$ 234,056
Other operations	22,196	16,880
Electric customer credits	(7,647)	(435)
Affiliate revenue	0	0
Operating revenue, net	276,760	250,501
Depreciation and amortization	42,507	40,851
Interest charges	31,157	31,718
Interest income	783	312
Federal and state income tax expense (benefit)	2,862	3,107
Net income (loss)	10,861	6,292
Additions to property, plant, and equipment	64,133	47,890
Equity investment in investee	18,172		$ 18,172
Goodwill	1,490,797		1,490,797
Total Segment Assets	6,309,981		6,278,382
Operating Segments | Cleco Power
Revenue [Abstract]
Electric operations	264,631	237,553
Other operations	22,195	16,365
Electric customer credits	(7,647)	(435)
Affiliate revenue	208	219
Operating revenue, net	279,387	253,702
Depreciation and amortization	40,388	38,758
Interest charges	17,656	18,104
Interest income	641	266
Federal and state income tax expense (benefit)	7,997	9,855
Net income (loss)	26,004	17,854
Additions to property, plant, and equipment	63,343	46,744
Equity investment in investee	18,172		18,172
Goodwill	1,490,797		1,490,797
Total Segment Assets	5,722,284		5,679,538
Operating Segments | OTHER
Revenue [Abstract]
Electric operations	(2,420)	(3,497)
Other operations	1	515
Electric customer credits	0	0
Affiliate revenue	15,669	14,734
Operating revenue, net	13,250	11,752
Depreciation and amortization	2,119	2,093
Interest charges	13,549	13,681
Interest income	190	113
Federal and state income tax expense (benefit)	(5,135)	(6,748)
Net income (loss)	(15,142)	(11,562)
Additions to property, plant, and equipment	790	1,146
Equity investment in investee	0		0
Goodwill	0		0
Total Segment Assets	618,513		619,943
ELIMINATIONS
Revenue [Abstract]
Electric operations	0	0
Other operations	0	0
Electric customer credits	0	0
Affiliate revenue	(15,877)	(14,953)
Operating revenue, net	(15,877)	(14,953)
Depreciation and amortization	0	0
Interest charges	(48)	(67)
Interest income	(48)	(67)
Federal and state income tax expense (benefit)	0	0
Net income (loss)	(1)	0
Additions to property, plant, and equipment	0	$ 0
Equity investment in investee	0		0
Goodwill	0		0
Total Segment Assets	$ (30,816)		$ (21,099)

Regulation and Rates (Details)

Regulation and Rates (Details)	Jan. 01, 2018	Dec. 31, 2017USD ($)	Sep. 30, 2016	Nov. 30, 2013	Mar. 31, 2018USD ($)claim	Mar. 31, 2018USD ($)	Oct. 31, 2017USD ($)	Feb. 28, 2017USD ($)
Regulation and Rates [Line Items]
Refund due to customers		$ 4,206,000			$ 11,805,000	$ 11,805,000
Tax Cuts and Jobs Act of 2017, customer refund liability					7,300,000	7,300,000
Federal and state combined statutory tax rate	26.00%	38.00%
Cleco Power
Regulation and Rates [Line Items]
Refund due to customers		$ 4,206,000			11,805,000	11,805,000
Payments received for capital expenditures subject to refund					4,300,000	4,300,000
Cleco Power | LPSC | Merger Commitments, cost savings
Regulation and Rates [Line Items]
Refund due to customers					$ 2,100,000	2,100,000
Cleco Power | MISO Transmission Rates | FERC
Regulation and Rates [Line Items]
Loss contingency, new claims filed, number | claim					2
Refund due to customers					$ 2,100,000	$ 2,100,000		$ 1,200,000
Target ROE allowed by FRP (in hundredths)			10.32%	12.38%
Cleco Power | FRP | LPSC
Regulation and Rates [Line Items]
Target ROE allowed by FRP (in hundredths)						10.00%
Percentage of retail earnings within range to be returned to customers (in hundredths)						60.00%
ROE for customer credit, low range (in hundredths)						10.90%
ROE for customer credit, high range (in hundredths)						11.75%
Cleco Power | FRP | LPSC | Maximum
Regulation and Rates [Line Items]
Target ROE allowed by FRP (in hundredths)						10.90%
Cleco Power | 2017 FRP Monitoring report | LPSC
Regulation and Rates [Line Items]
Refund due to customers							$ 0
Cleco Power | 2017 Merger Commitment Monitoring report | LPSC
Regulation and Rates [Line Items]
Tax Cuts and Jobs Act of 2017, customer refund liability							$ 1,200,000
Cleco Power | SSR | FERC
Regulation and Rates [Line Items]
Amount collected in SSR payments from MISO					20,300,000	$ 20,300,000
Cleco Power | SSR 2 | FERC
Regulation and Rates [Line Items]
Amount collected in SSR payments from MISO					$ 11,800,000	$ 11,800,000

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2017
Variable Interest Entity [Line Items]
Equity investment in investee	$ 18,172		$ 18,172
Components of Equity Method Investments [Abstract]
Total equity investment in investee	18,172		18,172
Cleco Power
Variable Interest Entity [Line Items]
Equity investment in investee	18,172		18,172
Components of Equity Method Investments [Abstract]
Purchase price	12,873		12,873
Cash contributions	6,399		6,399
Dividends	(1,100)		(1,100)
Total equity investment in investee	18,172		18,172
Comparison of Carrying Amount of Assets and Liabilities to Maximum Loss Exposure [Abstract]
Oxbow’s net assets/liabilities	36,345		36,345
Equity Method Investment, Summarized Financial Information [Abstract]
Operating revenue	863	$ 1,073
Operating expenses	863	1,073
Income before taxes	$ 0	$ 0
Cleco Power | Oxbow
Variable Interest Entity [Line Items]
Ownership percentage by Cleco Power (in hundredths)	50.00%
Ownership percentage by other parties (in hundredths)	50.00%
Comparison of Carrying Amount of Assets and Liabilities to Maximum Loss Exposure [Abstract]
Cleco Power’s 50% equity	$ 18,172		18,172
Cleco Power’s maximum exposure to loss	$ 18,172		$ 18,172

Litigation, Other Commitments61

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Litigation (Details) $ in Thousands	1 Months Ended					24 Months Ended
	Sep. 30, 2016	Jun. 30, 2016petition	Sep. 30, 2015USD ($)	Nov. 30, 2014	Nov. 30, 2013	Dec. 31, 2017USD ($)	Mar. 31, 2018USD ($)	Feb. 28, 2017USD ($)
Litigation [Abstract]
Provision for rate refund						$ 4,206	$ 11,805
Loss contingency, estimate of possible loss							4,600
FERC | MISO Transmission Rates
Litigation [Abstract]
Public utilities, requested rate increase (decrease), percentage (in hundredths)				0.50%
Gulf Coast Spinning start up costs
Litigation [Abstract]
Allegations by plaintiff, failure to perform			$ 6,500
Gulf Coast Spinning construction of cotton spinning facility
Litigation [Abstract]
Allegations by plaintiff, failure to perform			$ 60,000
Cleco Power
Litigation [Abstract]
Provision for rate refund						4,206	11,805
Cleco Power | LPSC 2014-2015 Fuel Audit
Litigation [Abstract]
Fuel costs						$ 536,200
Cleco Power | LPSC Nov2010-Dec2015 EAC audit
Litigation [Abstract]
Number of petitions filed with the U.S. Court of Appeals | petition		6
Cleco Power | FERC | MISO Transmission Rates
Litigation [Abstract]
Public utilities, approved return on equity, percentage (In hundredths)	10.32%				12.38%
Public utilities, proposed return on equity, percentage (in hundredths)		9.70%			6.68%
Provision for rate refund							$ 2,100	$ 1,200

Litigation, Other Commitments62

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Off-Balance Sheet Commitments and Guarantees (Details)	3 Months Ended
	Mar. 31, 2018USD ($)
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 | 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 Power | Financial Guarantee
Guarantor Obligations [Line Items]
Guarantor obligations, maximum exposure, undiscounted	$ 106,500,000

Litigation, Other Commitments63

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Other Commitments (Details) $ in Millions	3 Months Ended
	Mar. 31, 2018USD ($)	Dec. 31, 2012Barge	Dec. 31, 2008
Other Commitments [Line Items]
Tax benefits in excess of capital contributions	$ 18.3
Period of recognition of gross investment amortization expense (in years)	10 years
Number of barges | Barge		42
Cleco Holdings
Other Commitments [Line Items]
Membership interest in U.S Bank New Markets Tax Credit Fund (in hundredths)			99.90%
Equity contributions to be made to the Fund	$ 285.5
Net tax benefits and cash to be received from the Fund	$ 303.8
Energy investment, useful life	10 years
US Bancorp Community Development (USBCDC)
Other Commitments [Line Items]
Membership interest in U.S Bank New Markets Tax Credit Fund (in hundredths)			0.10%

Affiliate Transactions (Details

Affiliate Transactions (Details) - Cleco Power - USD ($) $ in Thousands	Mar. 31, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Accounts receivable - affiliate	$ 1,311	$ 1,355
Accounts payable - affiliate	9,969	8,697
Cleco Holdings
Related Party Transaction [Line Items]
Accounts receivable - affiliate	90	743
Accounts payable - affiliate	325	113
Support Group
Related Party Transaction [Line Items]
Accounts receivable - affiliate	1,221	608
Accounts payable - affiliate	9,644	8,582
Other
Related Party Transaction [Line Items]
Accounts receivable - affiliate	0	4
Accounts payable - affiliate	$ 0	$ 2

Intangible Assets - Narrative (

Intangible Assets - Narrative (Details) - USD ($)	3 Months Ended		12 Months Ended
	Mar. 31, 2018	Mar. 31, 2017	Dec. 31, 2008	Dec. 31, 2017
Finite-Lived Intangible Assets [Line Items]
Accumulated amortization	$ 52,917,000			$ 45,948,000
Reduction in revenue on intangible assets for power supply agreements	2,400,000	$ 3,500,000
Trade name
Finite-Lived Intangible Assets [Line Items]
Residual value	0
Amortization of intangible assets (less than)	$ 100,000	100,000
Finite-lived intangible asset, useful life	20 years
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Residual value	$ 0
Power supply agreements | Minimum
Finite-Lived Intangible Assets [Line Items]
Finite-lived intangible asset, useful life	5 years
Power supply agreements | Maximum
Finite-Lived Intangible Assets [Line Items]
Finite-lived intangible asset, useful life	17 years
Cleco Power
Finite-Lived Intangible Assets [Line Items]
Residual value	$ 0
Accumulated amortization	140,321,000		$ 0	$ 135,836,000
Cleco Power | 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
Amortization of intangible assets (less than)	$ 4,500,000	$ 3,500,000
Cleco Power | 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 Power | Financing costs
Finite-Lived Intangible Assets [Line Items]
Finite-lived intangible assets acquired			$ 1,500,000

Intangible Assets (Details)

Intangible Assets (Details) - USD ($)	Mar. 31, 2018	Dec. 31, 2017	Dec. 31, 2008
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	$ 160,798,000	$ 160,798,000
Accumulated amortization	(52,917,000)	(45,948,000)
Net intangible assets subject to amortization	107,881,000	114,850,000
Cleco Katrina/Rita right to bill and collect storm recovery charges
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	70,594,000	70,594,000
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	85,104,000	85,104,000
Trade name
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	5,100,000	5,100,000
Cleco Power
Finite-Lived Intangible Assets [Line Items]
Accumulated amortization	(140,321,000)	(135,836,000)	$ 0
Net intangible assets subject to amortization	37,216,000	41,701,000
Cleco Power | Cleco Katrina/Rita right to bill and collect storm recovery charges
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	$ 177,537,000	$ 177,537,000

Accumulated Other Comprehensi67

Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2018	Mar. 31, 2017
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	$ 43	$ (126)
Postretirement benefits adjustment during the period		(2,065)
Total other comprehensive income (loss), net of tax	43	(2,191)
TOTAL AOCI
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(2,921)	1,500
Amounts reclassified from accumulated other comprehensive income
Total other comprehensive income (loss), net of tax	43
Balances, end of period	(2,878)	(691)
POSTRETIREMENT BENEFIT NET LOSS
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(2,921)	1,500
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	43	(126)
Postretirement benefits adjustment during the period		(2,065)
Total other comprehensive income (loss), net of tax	43	(2,191)
Balances, end of period	(2,878)	(691)
NET LOSS ON CASH FLOW HEDGES
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	0	0
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	0	0
Postretirement benefits adjustment during the period		0
Total other comprehensive income (loss), net of tax	0	0
Balances, end of period	0	0
Cleco Power
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	233	164
Postretirement benefits adjustment during the period		(584)
Total other comprehensive income (loss), net of tax	297	(367)
Cleco Power | Interest Expense
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	64	53
Cleco Power | TOTAL AOCI
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(13,683)	(13,422)
Amounts reclassified from accumulated other comprehensive income
Total other comprehensive income (loss), net of tax	297
Balances, end of period	(13,386)	(13,789)
Cleco Power | POSTRETIREMENT BENEFIT NET LOSS
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(8,377)	(7,905)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	233	164
Postretirement benefits adjustment during the period		(584)
Total other comprehensive income (loss), net of tax	233	(420)
Balances, end of period	(8,144)	(8,325)
Cleco Power | POSTRETIREMENT BENEFIT NET LOSS | Interest Expense
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	0	0
Cleco Power | NET LOSS ON CASH FLOW HEDGES
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(5,306)	(5,517)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	0	0
Postretirement benefits adjustment during the period		0
Total other comprehensive income (loss), net of tax	64	53
Balances, end of period	(5,242)	(5,464)
Cleco Power | NET LOSS ON CASH FLOW HEDGES | Interest Expense
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net gain	$ 64	$ 53

Plan of Acquisition - (Details)

Plan of Acquisition - (Details)	Feb. 06, 2018USD ($)MW
Cleco Holdings | Acquisition Loan Facility, NRG South Central Acquisition
Business Acquisition [Line Items]
Debt amount | $	$ 300,000,000
Cleco Holdings | Term Loan Facility, NRG South Central Acquisition
Business Acquisition [Line Items]
Debt amount | $	300,000,000
Cleco Holdings | Incremental Revolving Facility, NRG Acquisition
Business Acquisition [Line Items]
Debt amount | $	$ 75,000,000
New Roads, Louisiana | Coal-fired Generating Station
Business Acquisition [Line Items]
Number of megawatts in station or facility	588
Jennings, Louisiana | Natural-gas-fired Peaking Facility
Business Acquisition [Line Items]
Number of megawatts in station or facility	300
NRG South Central
Business Acquisition [Line Items]
Business acquisition, transaction price agreed upon | $	$ 1,000,000,000
NRG South Central | Sterlington, Louisiana | Natural-gas-fired Generating Station
Business Acquisition [Line Items]
Number of megawatts in station or facility	176
NRG South Central | Jarreau, Louisiana | Natural-gas-fired Facility
Business Acquisition [Line Items]
Number of megawatts in station or facility	220
NRG South Central | Jarreau, Louisiana | Natural-gas-fired Peaking Facility
Business Acquisition [Line Items]
Number of megawatts in station or facility	210
NRG South Central | New Roads, Louisiana | Natural-gas-fired Generating Station
Business Acquisition [Line Items]
Number of megawatts in station or facility	540
NRG South Central | New Roads, Louisiana | Coal-fired Generating Facility
Business Acquisition [Line Items]
Number of megawatts in station or facility	580
NRG South Central | New Roads, Louisiana | Coal-fired Generating Station
Business Acquisition [Line Items]
Percentage of voting interests acquired	58.00%
NRG South Central | Jennings, Louisiana
Business Acquisition [Line Items]
Number of megawatts in station or facility	225
NRG South Central | Deweyville, Texas | Natural-gas-fired Generating Station
Business Acquisition [Line Items]
Number of megawatts in station or facility	1,263