10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

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

For the quarterly period ended June 30, 2018

Or

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

Commission file number 1-15759

CLECO CORPORATE HOLDINGS LLC

(Exact name of registrant as specified in its charter)

Louisiana (State or other jurisdiction of incorporation or organization)	72-1445282 (I.R.S. Employer Identification No.)
2030 Donahue Ferry Road, Pineville, Louisiana (Address of principal executive offices)	71360-5226 (Zip Code)
Registrant’s telephone number, including area code: (318) 484-7400

Commission file number 1-05663

CLECO POWER LLC

(Exact name of registrant as specified in its charter)

Louisiana (State or other jurisdiction of incorporation or organization)	72-0244480 (I.R.S. Employer Identification No.)
2030 Donahue Ferry Road, Pineville, Louisiana (Address of principal executive offices)	71360-5226 (Zip Code)
Registrant’s telephone number, including area code: (318) 484-7400
Indicate by check mark whether the Registrants: (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrants were required to file such reports) and (2) have been subject to such filing requirements for the past 90 days. Yes x  No ¨
Indicate by check mark whether the Registrants have submitted electronically and posted on their corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the Registrants were required to submit and post such files). Yes x  No ¨
Indicate by check mark whether Cleco Corporate Holdings LLC is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.  (Check one):   Large accelerated filer ¨     Accelerated filer ¨     Non-accelerated filer x (Do not check if a smaller reporting company) Smaller reporting company ¨ Emerging growth company ¨ If an emerging growth company, indicate by check mark if the Registrant has elected not to use the extended transition period for complying with any new or revised accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether Cleco Power LLC is a large accelerated filer, an accelerated filer, a non-accelerated filer, smaller reporting company, or an emerging growth company. See definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act.  (Check one): Large accelerated filer ¨     Accelerated filer ¨     Non-accelerated filer x (Do not check if a smaller reporting company) Smaller reporting company ¨ Emerging growth company ¨ If an emerging growth company, indicate by check mark if the Registrant has elected not to use the extended transition period for complying with any new or revised accounting standards provided pursuant to Section 13(a) of the Exchange Act. ¨
Indicate by check mark whether the Registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act)  Yes ¨    No x

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

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

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

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

This report should be read in its entirety as it pertains to each respective Registrant. The Notes to the Unaudited Condensed Consolidated Financial Statements are combined.

TABLE OF CONTENTS
		PAGE
GLOSSARY OF TERMS		3
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS		5
PART I	Financial Information
ITEM 1.	Cleco — Condensed Consolidated Financial Statements (Unaudited)	7
	Cleco Power — Condensed Consolidated Financial Statements (Unaudited)	16
	Notes to the Unaudited Condensed Consolidated Financial Statements	24
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	44
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	58
ITEM 4.	Controls and Procedures	60
PART II	Other Information
ITEM 1.	Legal Proceedings	61
ITEM 1A.	Risk Factors	61
ITEM 4.	Mine Safety Disclosures	61
ITEM 5.	Other Information	62
ITEM 6.	Exhibits	63
	Signatures	64

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

GLOSSARY OF TERMS

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

ABBREVIATION OR ACRONYM	DEFINITION
401(k) Plan	Cleco Power 401(k) Savings and Investment Plan
ABR	Alternate Base Rate which is the greater of the prime rate, the federal funds effective rate plus 0.50%, or LIBOR plus 1.0%
ADIT	Accumulated Deferred Income Tax
Acadia	Acadia Power Partners, LLC, previously a wholly owned subsidiary of Midstream. Acadia Power Partners, LLC was dissolved effective August 29, 2014.
Acadia Unit 1	Cleco Power’s 580-MW, combined cycle power plant located at the Acadia Power Station in Eunice, Louisiana
Acadia Unit 2	Entergy Louisiana’s 580-MW, combined cycle power plant located at the Acadia Power Station in Eunice, Louisiana, which is operated by Cleco Power
AFUDC	Allowance for Funds Used During Construction
ALJ	Administrative Law Judge
Amended Lignite Mining Agreement	Amended and restated lignite mining agreement effective December 29, 2009
AMI	Advanced Metering Infrastructure
AOCI	Accumulated Other Comprehensive Income (Loss)
ARO	Asset Retirement Obligation
ARRA	American Recovery and Reinvestment Act of 2009
Attala	Attala Transmission LLC, a wholly owned subsidiary of Cleco Holdings
BCI	British Columbia Investment Management Corporation, formerly bcIMC
CCR	Coal combustion by-products or residual
CEO	Chief Executive Officer
CFO	Chief Financial Officer
Cleco	Cleco Holdings and its subsidiaries
Cleco Cajun	Cleco Cajun LLC, formerly Cleco Energy LLC, a wholly owned subsidiary of Cleco Holdings
Cleco Corporation	Pre-merger entity that was converted to a limited liability company and changed its name to Cleco Corporate Holdings LLC on April 13, 2016
Cleco Group	Cleco Group LLC, a wholly owned subsidiary of Cleco Partners
Cleco Holdings	Cleco Corporate Holdings LLC, a wholly owned subsidiary of Cleco Group
Cleco Katrina/Rita	Cleco Katrina/Rita Hurricane Recovery Funding LLC, a wholly owned subsidiary of Cleco Power
Cleco Partners	Cleco Partners L.P., a Delaware limited partnership that is owned by a consortium of investors, including funds or investment vehicles managed by MIRA, BCI, John Hancock Financial, and other infrastructure investors
Cleco Power	Cleco Power LLC and its subsidiaries, a wholly owned subsidiary of Cleco Holdings
Cottonwood Energy	Cottonwood Energy Company LP, an indirect subsidiary of NRG South Central. Upon closing of the Purchase and Sale Agreement, Cottonwood Energy will become an indirect subsidiary of Cleco Holdings.
Coughlin	Cleco Power’s 775-MW, combined-cycle power plant located in St. Landry, Louisiana
DHLC	Dolet Hills Lignite Company, LLC, a wholly owned subsidiary of SWEPCO
Diversified Lands	Diversified Lands LLC, a wholly owned subsidiary of Cleco Holdings
Dolet Hills	A facility consisting of Dolet Hills Power Station, the Dolet Hills mine, and the Oxbow mine
Dolet Hills Power Station	A 650-MW generating unit at Cleco Power’s plant site in Mansfield, Louisiana. Cleco Power has a 50% ownership interest in the capacity of Dolet Hills.
EAC	Environmental Adjustment Clause
EBITDA	Earnings before interest, taxes, depreciation, and amortization
Entergy Gulf States	Entergy Gulf States Louisiana, LLC
Entergy Louisiana	Entergy Louisiana, LLC
EPA	U.S. Environmental Protection Agency
ERO	Electric Reliability Organization
Evangeline	Cleco Evangeline LLC, a wholly owned subsidiary of Midstream
FAC	Fuel Adjustment Clause
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
Fitch	Fitch Ratings, a credit rating agency
FTR	Financial Transmission Right
FRP	Formula Rate Plan
GAAP	Generally Accepted Accounting Principles in the U.S.
IRS	Internal Revenue Service
kWh	Kilowatt-hour(s)
LIBOR	London Interbank Offered Rate
LMP	Locational Marginal Price
LPSC	Louisiana Public Service Commission
Madison Unit 3	A 641-MW generating unit at Cleco Power’s plant site in Boyce, Louisiana

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

ABBREVIATION OR ACRONYM	DEFINITION
MATS	Mercury and Air Toxics Standards
Merger	Merger of Merger Sub with and into Cleco Corporation pursuant to the terms of the Merger Agreement which was completed on April 13, 2016
Merger Agreement	Agreement and Plan of Merger, dated as of October 17, 2014, by and among Cleco Partners, Merger Sub, and Cleco Corporation
Merger Commitments	Cleco Partners’, Cleco Group’s, Cleco Holdings’, and Cleco Power’s 77 commitments to the LPSC as defined in Docket No. U-33434 of which a performance report must be filed annually by October 31 for the 12 months ending June 30
Merger Sub	Cleco MergerSub Inc., previously an indirect wholly owned subsidiary of Cleco Partners that was merged with and into Cleco Corporation, with Cleco Corporation surviving the Merger, and Cleco Corporation converting to a limited liability company and changing its name to Cleco Holdings
Midstream	Cleco Midstream Resources LLC, a wholly owned subsidiary of Cleco Holdings
MIRA	Macquarie Infrastructure and Real Assets Inc.
MISO	Midcontinent Independent System Operator, Inc.
Moody’s	Moody’s Investors Service, a credit rating agency
MW	Megawatt(s)
MWh	Megawatt-hour(s)
NERC	North American Electric Reliability Corporation
NMTC	New Markets Tax Credit
NMTC Fund	USB NMTC Fund 2008-1 LLC was formed to invest in projects qualifying for New Markets Tax Credits and Solar Projects
Not Meaningful	A percentage comparison of these items is not statistically meaningful because the percentage difference is greater than 1,000%
NRG Energy	NRG Energy, Inc.
NRG South Central	NRG South Central Generating LLC
Other Benefits	Includes medical, dental, vision, and life insurance for Cleco’s retirees
Oxbow	Oxbow Lignite Company, LLC, 50% owned by Cleco Power and 50% owned by SWEPCO
PCB	Polychlorinated biphenyl
Perryville	Perryville Energy Partners, L.L.C., a wholly owned subsidiary of Cleco Holdings
Purchase and Sale Agreement	Purchase and Sale Agreement, dated as of February 6, 2018, by and among NRG Energy, NRG South Central, and Cleco Energy LLC (now Cleco Cajun)
RE	Regional Entity
Registrant(s)	Cleco Holdings and/or Cleco Power
ROE	Return on Equity
RTO	Regional Transmission Organization
S&P	Standard & Poor’s Ratings Services, a credit rating agency
SEC	U.S. Securities and Exchange Commission
SERP	Supplemental Executive Retirement Plan
SPP	Southwest Power Pool
SPP RE	Southwest Power Pool Regional Entity
SSR	System Support Resource
START	Strategic Alignment and Real-Time Transformation
Support Group	Cleco Support Group LLC, a wholly owned subsidiary of Cleco Holdings
SWEPCO	Southwestern Electric Power Company, an electric utility subsidiary of American Electric Power Company, Inc.
TCJA	Tax Cuts and Jobs Act of 2017
Teche Unit 3	A 359-MW generating unit at Cleco Power’s plant site in Baldwin, Louisiana
VaR	Value-at-Risk

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CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

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

• the effects of the Merger on Cleco Holdings’ and Cleco Power’s business relationships, operating results, and business generally,

• regulatory factors, such as changes in rate-setting practices or policies; the unpredictability in political actions of governmental regulatory bodies; adverse regulatory ratemaking actions; recovery of investments made under traditional regulation; recovery of storm restoration costs; the frequency, timing, and amount of rate increases or decreases; the impact that rate cases or requests for FRP extensions may have on operating decisions of Cleco Power; the results of periodic NERC, LPSC, and FERC audits; participation in MISO and the related operating challenges and uncertainties, including increased wholesale competition relative to additional suppliers; and compliance with the ERO reliability standards for bulk power systems by Cleco Power,

• the ability to recover fuel costs through the FAC,

• the ability to close the proposed transaction with NRG Energy and NRG South Central, including the related financings,

• the ability to successfully integrate the assets to be acquired in the proposed transaction with NRG Energy and NRG South Central, if completed, into Cleco’s operations,

• factors affecting utility operations, such as unusual weather conditions or other natural phenomena; catastrophic weather-related damage caused by hurricanes and other storms or severe drought conditions; unscheduled generation outages; unanticipated maintenance or repairs; unanticipated changes to fuel costs or fuel supply costs, shortages, transportation problems, or other developments; fuel mix of Cleco’s generating facilities; decreased customer

load; environmental incidents and compliance costs; and power transmission system constraints,

• reliance on third parties for determination of Cleco Power’s commitments and obligations to markets for generation resources and reliance on third-party transmission services,

• global and domestic economic conditions, including the ability of customers to continue paying their utility bills, related growth and/or down-sizing of businesses in Cleco’s service area, monetary fluctuations, changes in commodity prices, and inflation rates, 

• political uncertainty in the U.S., including the ongoing debates related to the U.S. federal government budget and debt ceiling, and volatility and disruption in global capital and credit markets,

• the ability of the lignite reserves at Dolet Hills to provide sufficient fuel to the Dolet Hills Power Station until at least 2036,

• Cleco Power’s ability to maintain its right to sell wholesale power at market-based rates within its control area, 

• Cleco Power’s dependence on energy from sources other than its facilities and future sources of such additional energy,

• reliability of Cleco Power’s generating facilities,

• the imposition of energy efficiency requirements or increased conservation efforts of customers,

• the impact of current or future environmental laws and regulations, including those related to CCRs, greenhouse gases, and energy efficiency that could limit or terminate the operation of certain generating units, increase costs, or reduce customer demand for electricity,

• the ability to recover costs of compliance with environmental laws and regulations, including those through the EAC,

• financial or regulatory accounting principles or policies imposed by FASB, the SEC, FERC, the LPSC, or similar entities with regulatory or accounting oversight, 

• changing market conditions and a variety of other factors associated with physical energy, financial transactions, and energy service activities, including, but not limited to, price, basis, credit, liquidity, volatility, capacity, transmission, interest rates, and warranty risks,

• legal, environmental, and regulatory delays and other obstacles associated with acquisitions (including the NRG South Central acquisition), reorganizations, investments in joint ventures, or other capital projects,

• costs and other effects of legal and administrative proceedings, settlements, investigations, claims, and other matters,

• the availability and use of alternative sources of energy and technologies, such as wind, solar, battery storage, and distributed generation,

• changes in federal, state, or local laws (including the TCJA and other tax laws), changes in tax rates, disallowances of

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

tax positions, or changes in other regulating policies that may result in a change to tax benefits or expenses,

• the restriction on the ability of Cleco Power to make distributions to Cleco Holdings in certain instances, as a result of the Merger Commitments,

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

• acts of terrorism, cyber attacks, data security breaches or other attempts to disrupt Cleco’s business or the business of third parties, or other man-made disasters,

• credit ratings of Cleco Holdings and Cleco Power,

• the ability to remain in compliance with debt covenants,

• the availability or cost of capital resulting from changes in global markets, Cleco’s business or financial condition, interest rates, or market perceptions of the electric utility industry and energy-related industries, and

• employee workforce factors, including aging workforce, changes in management, and inadequate resources.

For more discussion of these factors and other factors that could cause actual results to differ materially from those contemplated in the Registrants’ forward-looking statements, see Part II, Item 1A, “Risk Factors” in this report and in Part I, Item 1A, “Risk Factors” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

All subsequent written and oral forward-looking statements attributable to the Registrants, or persons acting on their behalf, are expressly qualified in their entirety by the factors identified above.

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

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

PART I — FINANCIAL INFORMATION

ITEM 1.  CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Cleco

These unaudited Condensed Consolidated Financial Statements should be read in conjunction with Cleco’s Consolidated Financial Statements and Notes included in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017. For more information on the basis of presentation, see “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — Basis of Presentation.”

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017
Operating revenue
Electric operations	$	294,213		$	287,435
Other operations	18,685			21,465
Gross operating revenue	312,898			308,900
Electric customer credits	(13,637		)	(239		)
Operating revenue, net	299,261			308,661
Operating expenses
Fuel used for electric generation	77,562			87,974
Power purchased for utility customers	50,154			43,356
Other operations	30,511			26,235
Maintenance	24,192			24,400
Depreciation and amortization	41,807			41,552
Taxes other than income taxes	11,326			11,874
Total operating expenses	235,552			235,391
Operating income	63,709			73,270
Interest income	1,427			381
Allowance for equity funds used during construction	3,224			1,440
Other income	798			475
Other expense	(3,745		)	(3,281		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	32,957			31,022
Allowance for borrowed funds used during construction	(1,048		)	(401		)
Total interest charges	31,909			30,621
Income before income taxes	33,504			41,664
Federal and state income tax expense	7,665			16,220
Net income	$	25,839		$	25,444
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017
Net income	$	25,839	$	25,444
Other comprehensive income, net of tax
Postretirement benefits gain (net of tax expense of $87 in 2018 and $37 in 2017)	247		60
Total other comprehensive income, net of tax	247		60
Comprehensive income, net of tax	$	26,086	$	25,504
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017
Operating revenue
Electric operations	$	556,424		$	521,491
Other operations	40,881			38,345
Gross operating revenue	597,305			559,836
Electric customer credits	(21,284		)	(674		)
Operating revenue, net	576,021			559,162
Operating expenses
Fuel used for electric generation	144,578			157,846
Power purchased for utility customers	103,313			75,320
Other operations	58,477			55,561
Maintenance	53,311			48,924
Depreciation and amortization	84,314			82,402
Taxes other than income taxes	23,584			24,376
Total operating expenses	467,577			444,429
Operating income	108,444			114,733
Interest income	2,211			693
Allowance for equity funds used during construction	5,587			2,350
Other income	981			1,845
Other expense	(6,928		)	(6,219		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	64,988			62,967
Allowance for borrowed funds used during construction	(1,921		)	(628		)
Total interest charges	63,067			62,339
Income before income taxes	47,228			51,063
Federal and state income tax expense	10,528			19,327
Net income	$	36,700		$	31,736
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017
Net income	$	36,700	$	31,736
Other comprehensive income (loss), net of tax
Postretirement benefits gain (loss) (net of tax expense of $102 in 2018 and tax benefit of $1,333 in 2017)	290		(2,131		)
Total other comprehensive income (loss), net of tax	290		(2,131		)
Comprehensive income, net of tax	$	36,990	$	29,605
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT JUNE 30, 2018			AT DEC. 31, 2017
Assets
Current assets
Cash and cash equivalents	$	116,312		$	119,040
Restricted cash and cash equivalents	9,945			13,081
Customer accounts receivable (less allowance for doubtful accounts of $1,054 in 2018 and $1,457 in 2017)	65,886			60,117
Other accounts receivable	24,648			30,806
Unbilled revenue	46,480			36,398
Fuel inventory, at average cost	78,621			87,520
Materials and supplies, at average cost	87,927			85,404
Energy risk management assets	26,077			7,396
Accumulated deferred fuel	36,786			13,980
Cash surrender value of company-/trust-owned life insurance policies	83,365			83,117
Prepayments	8,249			9,050
Regulatory assets	21,361			24,670
Other current assets	1,749			1,146
Total current assets	607,406			571,725
Property, plant, and equipment
Property, plant, and equipment	3,691,344			3,594,525
Accumulated depreciation	(251,348		)	(192,348		)
Net property, plant, and equipment	3,439,996			3,402,177
Construction work in progress	238,218			186,629
Total property, plant, and equipment, net	3,678,214			3,588,806
Equity investment in investee	18,172			18,172
Goodwill	1,490,797			1,490,797
Restricted cash and cash equivalents	19,080			20,081
Regulatory assets	417,849			432,358
Intangible assets	99,889			114,850
Other deferred charges	54,204			41,593
Total assets	$	6,385,611		$	6,278,382
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.
(Continued on next page)

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CLECO
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT JUNE 30, 2018			AT DEC. 31, 2017
Liabilities and member’s equity
Liabilities
Current liabilities
Long-term debt due within one year	$	20,405		$	19,193
Accounts payable	145,459			147,562
Customer deposits	60,494			58,582
Provision for rate refund	25,311			4,206
Taxes payable, net	46,237			22,698
Interest accrued	16,024			14,703
Deferred compensation	11,500			12,132
Other current liabilities	24,027			21,278
Total current liabilities	349,457			300,354
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	624,584			614,812
Postretirement benefit obligations	243,740			242,135
Regulatory liabilities - deferred taxes, net	136,447			140,426
Restricted storm reserve	14,955			14,469
Other deferred credits	34,625			33,724
Total long-term liabilities and deferred credits	1,054,351			1,045,566
Long-term debt, net	2,888,356			2,836,105
Total liabilities	4,292,164			4,182,025
Commitments and contingencies (Note 12)
Member’s equity
Membership interest	2,069,376			2,069,376
Retained earnings	26,702			29,902
Accumulated other comprehensive loss	(2,631		)	(2,921		)
Total member’s equity	2,093,447			2,096,357
Total liabilities and member’s equity	$	6,385,611		$	6,278,382
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO
Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018				2017
Operating activities
Net income	$	36,700			$	31,736
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	92,756				93,943
Provision for doubtful accounts	84				2,587
Unearned compensation expense	2,005				1,909
Allowance for equity funds used during construction	(5,587		)		(2,350		)
Deferred income taxes	5,691				16,881
Deferred fuel costs	(26,339		)		(305		)
Cash surrender value of company-/trust-owned life insurance	(248		)		(2,393		)
Changes in assets and liabilities
Accounts receivable	(8,309		)		(30,205		)
Unbilled revenue	(10,083		)		(5,677		)
Fuel inventory and materials and supplies	6,500				(9,652		)
Accounts payable	306				(23,828		)
Customer deposits	6,746				5,646
Provision for merger commitments	(1,847		)		(6,761		)
Postretirement benefit obligations	1,998				2,696
Regulatory assets and liabilities, net	7,917				4,896
Other deferred accounts	1,612				(8,631		)
Taxes accrued	22,621				15,000
Interest accrued	1,321				965
Other operating	1,964				608
Net cash provided by operating activities	135,808				87,065
Investing activities
Additions to property, plant, and equipment	(135,702		)		(128,693		)
Allowance for equity funds used during construction	5,587				2,350
Reimbursement for property loss	1,223				105
Issuance of note receivable	(16,800		)		—
Return of equity investment in tax credit fund	2,775				841
Other investing	672				328
Net cash used in investing activities	(142,245		)		(125,069		)
Financing activities
Draws on credit facilities	—				114,000
Payments on credit facilities	—				(29,000		)
Issuances of long-term debt	50,000				—
Repayment of long-term debt	(9,700		)		(9,060		)
Distributions to member	(39,900		)		(55,655		)
Other financing	(828		)		(849		)
Net cash (used in) provided by financing activities	(428		)		19,436
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	(6,865		)		(18,568		)
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	$	145,337		(2)	$	51,003
Supplementary cash flow information
Interest paid, net of amount capitalized	$	60,528			$	57,937
Income taxes paid, net	$	272			$	1
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	40,011			$	13,125
Non-cash additions to property, plant, and equipment	$	—			$	3,009
Incurrence of capital lease obligation - barges	$	16,800			$	—
(1) Includes cash and cash equivalents of $119,040, current restricted cash and cash equivalents of $13,081, and non-current restricted cash and cash equivalents of $20,081. (2) Includes cash and cash equivalents of $116,312, current restricted cash and cash equivalents of $9,945, and non-current restricted cash and cash equivalents of $19,080. The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

14

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited)
(THOUSANDS)	MEMBERSHIP INTEREST		RETAINED EARNINGS			AOCI			TOTAL MEMBER’S EQUITY
Balances, Dec. 31, 2017	$	2,069,376	$	29,902		$	(2,921	)	$	2,096,357
Distributions to member	—		(39,900		)	—			(39,900		)
Net income	—		36,700			—			36,700
Other comprehensive income, net of tax	—		—			290			290
Balances, June 30, 2018	$	2,069,376	$	26,702		$	(2,631	)	$	2,093,447
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

15

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

ITEM 1.CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Cleco Power

These unaudited Condensed Consolidated Financial Statements should be read in conjunction with Cleco Power’s Consolidated Financial Statements and Notes included in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017. For more information on the basis of presentation, see “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — Basis of Presentation.”

16

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017
Operating revenue
Electric operations	$	296,633		$	289,855
Other operations	18,685			20,950
Affiliate revenue	220			221
Gross operating revenue	315,538			311,026
Electric customer credits	(13,637		)	(239		)
Operating revenue, net	301,901			310,787
Operating expenses
Fuel used for electric generation	77,562			87,974
Power purchased for utility customers	50,154			43,356
Other operations	26,812			27,649
Maintenance	24,138			24,264
Depreciation and amortization	39,720			39,473
Taxes other than income taxes	10,913			11,404
Total operating expenses	229,299			234,120
Operating income	72,602			76,667
Interest income	1,313			328
Allowance for equity funds used during construction	3,224			1,440
Other income	797			165
Other expense	(3,099		)	(2,393		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	19,155			17,812
Allowance for borrowed funds used during construction	(1,048		)	(401		)
Total interest charges	18,107			17,411
Income before income taxes	56,730			58,796
Federal and state income tax expense	13,710			23,063
Net income	$	43,020		$	35,733
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

17

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017
Net income	$	43,020	$	35,733
Other comprehensive income, net of tax
Postretirement benefits gain (net of tax expense of $94 in 2018 and $120 in 2017)	267		193
Amortization of interest rate derivatives to earnings (net of tax expense of $22 in 2018 and $33 in 2017)	64		53
Total other comprehensive income, net of tax	331		246
Comprehensive income, net of tax	$	43,351	$	35,979
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017
Operating revenue
Electric operations	$	561,264		$	527,408
Other operations	40,880			37,315
Affiliate revenue	428			440
Gross operating revenue	602,572			565,163
Electric customer credits	(21,284		)	(674		)
Operating revenue, net	581,288			564,489
Operating expenses
Fuel used for electric generation	144,578			157,846
Power purchased for utility customers	103,313			75,320
Other operations	54,116			57,913
Maintenance	53,216			48,684
Depreciation and amortization	80,109			78,230
Taxes other than income taxes	22,831			23,404
Total operating expenses	458,163			441,397
Operating income	123,125			123,092
Interest income	1,953			594
Allowance for equity funds used during construction	5,587			2,350
Other income	1,537			375
Other expense	(5,708		)	(4,391		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	37,684			36,143
Allowance for borrowed funds used during construction	(1,921		)	(628		)
Total interest charges	35,763			35,515
Income before income taxes	90,731			86,505
Federal and state income tax expense	21,707			32,918
Net income	$	69,024		$	53,587
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

19

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017
Net income	$	69,024	$	53,587
Other comprehensive income (loss), net of tax
Postretirement benefits gain (loss) (net of tax expense of $177 in 2018 and tax benefit $142 in 2017)	500		(227		)
Amortization of interest rate derivatives to earnings (net of tax expense of $45 in 2018 and $66 in 2017)	128		106
Total other comprehensive income (loss), net of tax	628		(121		)
Comprehensive income, net of tax	$	69,652	$	53,466
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

20

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT JUNE 30, 2018			AT DEC. 31, 2017
Assets
Property, plant, and equipment	$	4,985,054		$	4,893,484
Accumulated depreciation	(1,763,394		)	(1,712,590		)
Net property, plant, and equipment	3,221,660			3,180,894
Construction work in progress	238,151			185,507
Total utility plant and equipment, net	3,459,811			3,366,401
Current assets
Cash and cash equivalents	71,579			69,816
Restricted cash and cash equivalents	9,945			13,081
Customer accounts receivable (less allowance for doubtful accounts of $1,054 in 2018 and $1,457 in 2017)	65,886			60,117
Accounts receivable - affiliate	698			1,355
Other accounts receivable	24,149			30,680
Unbilled revenue	46,480			36,398
Fuel inventory, at average cost	78,621			87,520
Materials and supplies, at average cost	87,927			85,404
Energy risk management assets	26,077			7,396
Accumulated deferred fuel	36,786			13,980
Cash surrender value of company-owned life insurance policies	20,394			20,278
Prepayments	6,700			7,236
Regulatory assets	12,504			15,812
Other current assets	905			475
Total current assets	488,651			449,548
Equity investment in investee	18,172			18,172
Restricted cash and cash equivalents	19,059			20,060
Regulatory assets	248,494			257,408
Intangible asset	31,707			41,701
Other deferred charges	50,868			35,451
Total assets	$	4,316,762		$	4,188,741
Liabilities and member’s equity
Member’s equity	$	1,549,331		$	1,550,679
Long-term debt, net	1,397,700			1,341,475
Total capitalization	2,947,031			2,892,154
Current liabilities
Long-term debt due within one year	20,405			19,193
Accounts payable	137,599			134,374
Accounts payable - affiliate	10,701			8,697
Customer deposits	60,494			58,582
Provision for rate refund	25,311			4,206
Taxes payable, net	64,562			31,611
Interest accrued	8,490			7,083
Other current liabilities	18,826			16,172
Total current liabilities	346,388			279,918
Commitments and contingencies (Note 12)
Accumulated deferred federal and state income taxes, net	668,128			656,362
Postretirement benefit obligations	172,220			173,747
Regulatory liabilities - deferred taxes, net	136,447			140,426
Restricted storm reserve	14,955			14,469
Other deferred credits	31,593			31,665
Total long-term liabilities and deferred credits	1,023,343			1,016,669
Total liabilities and member’s equity	$	4,316,762		$	4,188,741
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

21

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018				2017
Operating activities
Net income	$	69,024			$	53,587
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	83,199				82,292
Provision for doubtful accounts	84				2,500
Unearned compensation expense	609				1,023
Allowance for equity funds used during construction	(5,587		)		(2,350		)
Deferred income taxes	7,566				3,916
Deferred fuel costs	(26,339		)		(305		)
Changes in assets and liabilities
Accounts receivable	(7,933		)		(30,240		)
Accounts receivable, affiliate	1,639				1,560
Unbilled revenue	(10,083		)		(5,677		)
Fuel inventory and materials and supplies	6,500				(9,652		)
Prepayments	65				(1,438		)
Accounts payable	5,465				(21,455		)
Accounts payable, affiliate	(1,740		)		(58		)
Customer deposits	6,746				5,646
Provision for merger commitments	(1,847		)		(6,761		)
Postretirement benefit obligations	1,784				2,472
Regulatory assets and liabilities, net	6,923				3,902
Other deferred accounts	1,949				(8,665		)
Taxes accrued	32,033				21,753
Interest accrued	1,407				1,037
Other operating	2,317				1,436
Net cash provided by operating activities	173,781				94,523
Investing activities
Additions to property, plant, and equipment	(135,334		)		(127,297		)
Allowance for equity funds used during construction	5,587				2,350
Reimbursement of property loss	1,223				105
Issuance of note receivable	(16,800		)		—
Other investing	672				958
Net cash used in investing activities	(144,652		)		(123,884		)
Financing activities
Draws on credit facility	—				90,000
Payments on credit facility	—				(15,000		)
Issuances of long-term debt	50,000				—
Repayment of long-term debt	(9,700		)		(9,060		)
Distributions to parent	(71,000		)		(60,000		)
Other financing	(803		)		(595		)
Net cash (used in) provided by financing activities	(31,503		)		5,345
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	(2,374		)		(24,016		)
Cash, cash equivalents, restricted cash, and restricted cash equivalents at beginning of period	102,957			(1)	67,955
Cash, cash equivalents, restricted cash, and restricted cash equivalents at end of period	$	100,583		(2)	$	43,939
Supplementary cash flow information
Interest paid, net of amount capitalized	$	33,940			$	31,907
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	39,974			$	13,081
Non-cash additions to property, plant, and equipment	$	—			$	3,009
Incurrence of capital lease obligation - barges	$	16,800			$	—
(1) Includes cash and cash equivalents of $69,816, current restricted cash and cash equivalents of $13,081, and non-current restricted cash and cash equivalents of $20,060. (2) Includes cash and cash equivalents of $71,579, current restricted cash and cash equivalents of $9,945, and non-current restricted cash and cash equivalents of $19,059. The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited)
(THOUSANDS)	MEMBER’S EQUITY			AOCI			TOTAL  MEMBER’S EQUITY
Balances, Dec. 31, 2017	$	1,564,362		$	(13,683	)	$	1,550,679
Distributions to parent	(71,000		)	—			(71,000		)
Net income	69,024			—			69,024
Other comprehensive income, net of tax	—			628			628
Balances, June 30, 2018	$	1,562,386		$	(13,055	)	$	1,549,331
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

23

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

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

Notes to the Unaudited Condensed Consolidated Financial Statements

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 JUNE 30, 2018		AT DEC. 31, 2017
Current
Cleco Katrina/Rita’s storm recovery bonds	$	8,144	$	8,597
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	601		3,284
Total current	9,945		13,081
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	14,934		14,456
Cleco Power’s charitable contributions	2,933		3,575
Cleco Power’s rate credit escrow	1,192		2,029
Total non-current	19,080		20,081
Total restricted cash and cash equivalents	$	29,025	$	33,162

24

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current
Cleco Katrina/Rita’s storm recovery bonds	$	8,144	$	8,597
Charitable contributions	1,200		1,200
Rate credit escrow	601		3,284
Total current	9,945		13,081
Non-current
Future storm restoration costs	14,934		14,456
Charitable contributions	2,933		3,575
Rate credit escrow	1,192		2,029
Total non-current	19,059		20,060
Total restricted cash and cash equivalents	$	29,004	$	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 June 30, 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 $10.6 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 June 30, 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 each reporting period presented, the Registrants did not enter into any contracts to mitigate the volatility in interest rate risk.

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

25

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

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 revenue requirements with rates effective June 1 of each year.

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 and six months ended June 30, 2018, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	CLECO POWER			OTHER				ELIMINATIONS			TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	107,805		$	—			$	—		$	107,805
Commercial (1)	71,865			—				—			71,865
Industrial (1)	40,679			—				—			40,679
Other retail (1)	3,793			—				—			3,793
Surcharge	6,193			—				—			6,193
Total retail revenue	$	230,335		$	—			$	—		$	230,335
Wholesale, net (1)	54,662			(2,420		)	(2)	—			52,242
Transmission	11,943			—				—			11,943
Other (3)	(6,895		)	—				—			(6,895		)
Total revenue from contracts with customers	$	290,045		$	(2,420	)		$	—		$	287,625
Revenue unrelated to contracts with customers
Affiliate	$	220		$	17,273			$	(17,493	)	$	—
Other	11,636			—				—			11,636
Total revenue unrelated to contracts with customers	11,856			17,273				(17,493		)	11,636
Operating revenue, net	$	301,901		$	14,853			$	(17,493	)	$	299,261

⁽¹⁾ Includes fuel recovery revenue.

⁽²⁾ Amortization of intangible assets related to wholesale power supply agreements.

⁽³⁾ Other revenue from contracts with customers includes $13.6 million of electric customer credits, partially offset by $4.1 million of other miscellaneous fee revenue, and $2.6 million of Teche Unit 3 SSR revenue, net of $0.3 million of reserves for capital expenditures.

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	FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	CLECO POWER			OTHER				ELIMINATIONS			TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	199,195		$	—			$	—		$	199,195
Commercial (1)	138,560			—				—			138,560
Industrial (1)	78,065			—				—			78,065
Other retail (1)	7,594			—				—			7,594
Surcharge	11,431			—				—			11,431
Total retail revenue	$	434,845		$	—			$	—		$	434,845
Wholesale, net (1)	101,631			(4,840		)	(2)	—			96,791
Transmission	26,448			—				—			26,448
Other (3)	(6,852		)	1				—			(6,851		)
Total revenue from contracts with customers	$	556,072		$	(4,839	)		$	—		$	551,233
Revenue unrelated to contracts with customers
Affiliate	$	428		$	32,942			$	(33,370	)	$	—
Other	24,788			—				—			24,788
Total revenue unrelated to contracts with customers	25,216			32,942				(33,370		)	24,788
Operating revenue, net	$	581,288		$	28,103			$	(33,370	)	$	576,021

⁽¹⁾ Includes fuel recovery revenue.

⁽²⁾ Amortization of intangible assets related to wholesale power supply agreements.

⁽³⁾ Other revenue from contracts with customers includes $21.3 million of electric customer credits, partially offset by $8.6 million of other miscellaneous fee revenue, and $5.8 million of Teche Unit 3 SSR revenue, net of $2.2 million of reserves for capital expenditures.

Transaction Price Allocated to Remaining Performance Obligations

For 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 June 30, 2018, and (2) when Cleco expects to recognize this revenue:

REMAINING PERFORMANCE OBLIGATIONS	(THOUSANDS)
Six months ending Dec. 31, 2018	$	24,213
Years ending Dec. 31,
2019	23,874
2020	7,068
2021	7,068
2022	6,468
Thereafter	10,210
Total remaining performance obligations	$	78,901

Unsatisfied performance obligations primarily relate to stand-ready obligations as part of fixed capacity minimums.

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.

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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 SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Transfer of cash from restricted accounts, net	$	6,003		$	—
Net cash used in investing activities	$	(119,066	)	$	(125,069	)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	$	(12,565	)	$	(18,568	)
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	$	10,512		$	51,003

Cleco Power
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Transfer of cash from restricted accounts, net	$	6,003		$	—
Net cash used in investing activities	$	(117,881	)	$	(123,884	)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	$	(18,013	)	$	(24,016	)
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	$	3,469		$	43,939

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 JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	29,256		$	26,235
Total operating expenses	$	238,412		$	235,391
Operating income	$	70,249		$	73,270
Other expense	$	(260	)	$	(3,281	)

Cleco
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	61,244		$	55,561		*
Total operating expenses	$	450,114		$	444,429
Operating income	$	109,048		$	114,733
Other expense	$	(534	)	$	(6,219	)
* Also reflects less than $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 JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	29,782		$	27,649
Total operating expenses	$	236,253		$	234,120
Operating income	$	74,534		$	76,667
Other expense	$	(260	)	$	(2,393	)

Cleco Power
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	61,770		$	57,913
Total operating expenses	$	445,254		$	441,397
Operating income	$	119,235		$	123,092
Other expense	$	(534	)	$	(4,391	)

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.

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

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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 JUNE 30, 2018			AT DEC. 31, 2017
Regulatory liabilities - deferred taxes, net	$	(136,447	)	$	(140,426	)
Mining costs	2,549			3,823
Interest costs	4,340			4,499
AROs	2,824			2,762
Postretirement costs	136,644			142,764
Tree trimming costs	8,015			7,193
Training costs	6,474			6,552
Surcredits, net	289			2,173
AMI deferred revenue requirement	3,954			4,227
Emergency declarations	3,781			4,131
Production operations and maintenance expenses	5,827			8,625
AFUDC equity gross-up	71,295			71,205
Acadia Unit 1 acquisition costs	2,283			2,336
Financing costs	8,108			8,293
MISO integration costs	—			468
Coughlin transaction costs	953			968
Corporate franchise tax, net	1,500			153
MATS costs	—			2,564
Non-service cost of postretirement benefits	2,136			—
Other	26			484
Total regulatory assets	260,998			273,220
Accumulated deferred fuel	36,786			13,980
Total regulatory assets, net	$	161,337		$	146,774

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

(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Total Cleco Power regulatory assets, net	$	161,337	$	146,774
Cleco Merger adjustments (1)
Fair value of long-term debt	142,922		147,145
Postretirement costs	20,381		21,375
Financing costs	8,450		8,623
Debt issuance costs	6,459		6,665
Total Cleco regulatory assets, net	$	339,549	$	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 are being deferred to a regulatory asset and will be 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.”

Note 5 — Fair Value Accounting

The amounts reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at June 30, 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 JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,903,190	$	2,865,196	$	2,866,955	$	2,921,325

* The carrying value of long-term debt does not include deferred issuance costs of $11.1 million and $11.6 million at June 30, 2018, and December 31, 2017, respectively.

Cleco Power
	AT JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,410,267	$	1,518,752	$	1,369,810	$	1,535,234

* The carrying value of long-term debt does not include deferred issuance costs of $8.8 million and $9.1 million at June 30, 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 JUNE 30, 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	$	141,290	$	—	$	141,290	$	—	$	144,302	$	—	$	144,302	$	—
FTRs	26,077		—		—		26,077		7,396		—		—		7,396
Total assets	$	167,367	$	—	$	141,290	$	26,077	$	151,698	$	—	$	144,302	$	7,396
Liability description
FTRs	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352
Total liabilities	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352

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Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS)	AT JUNE 30, 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	$	96,568	$	—	$	96,568	$	—	$	95,681	$	—	$	95,681	$	—
FTRs	26,077		—		—		26,077		7,396		—		—		7,396
Total assets	$	122,645	$	—	$	96,568	$	26,077	$	103,077	$	—	$	95,681	$	7,396
Liability description
FTRs	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352
Total liabilities	$	944	$	—	$	—	$	944	$	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 JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018			2017
Beginning balance	$	4,283		$	4,418		$	7,044		$	7,683
Unrealized gains (losses)*	2,420			(2,460		)	2,420			(2,460		)
Purchases	25,112			22,843			25,483			23,118
Settlements	(6,682		)	(6,858		)	(9,814		)	(10,398		)
Ending balance	$	25,133		$	17,943		$	25,133		$	17,943
* 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 June 30, 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 June 30, 2018	$	26,077	$	944	RTO auction pricing	FTR price - per MWh	$	(3.84	)	$	7.42
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 June 30, 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 $112.5 million, $9.9 million, and $18.9 million, respectively, at June 30, 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 $67.8 million, $9.9 million, and $18.9 million, respectively, at June 30, 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.

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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 six months ended June 30, 2018, and the year ended December 31, 2017, Cleco did not 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 June 30, 2018, and December 31, 2017:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2018		AT DEC. 31, 2017
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	26,077	$	7,396
Current	Other current liabilities	944		352
Commodity-related contracts, net		$	25,133	$	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 six months ended June 30, 2018, and 2017:

	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	DERIVATIVES LINE ITEM	2018			2017			2018			2017
Commodity contracts
FTRs(1)	Electric operations	$	17,841		$	11,947		$	35,991		$	21,110
FTRs(1)	Power purchased for utility customers	(7,027		)	(6,327		)	(12,693		)	(10,992		)
Total		$	10,814		$	5,620		$	23,298		$	10,118

⁽¹⁾ For the three and six months ended June 30, 2018, unrealized gains associated with FTRs of $2.4 million were reported through Accumulated deferred fuel on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. For the three and six months ended June 30, 2017, unrealized losses associated with FTRs of $2.5 million 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 June 30, 2018, and December 31, 2017, was 19.3 million MWh and 9.0 million MWh, respectively.

Note 6 — Debt

On December 18, 2017, Cleco Power entered into an agreement for the issuance and sale in a private placement of an aggregate principal amount of $175.0 million of senior notes. The senior notes were issued in two tranches. The first tranche was issued on December 18, 2017, with a principal amount 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 a principal amount of $50.0 million at an interest rate of 3.17%, with a final maturity date of December 16, 2024. The proceeds from the issuances and sales 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.”

On July 31, 2018, Cleco amended its $300.0 million bank term loan agreement and its $100.0 million revolving credit facility agreement to release any and all collateral from all of its debt obligations under those agreements. As a result of the release of collateral, Cleco Holdings expects Moody’s and Fitch to update Cleco Holdings’ senior debt rating. For more information on Cleco’s credit ratings and their impacts, see Note 12 — “Litigation, Other Commitment and Contingencies,

and Disclosures about Guarantees — Risks and Uncertainties.”

On April 2, 2018, Cleco Power entered into a capital lease agreement for use of 42 dedicated barges to transport petroleum coke and limestone to Madison Unit 3. For more information on the capital lease agreement, see Note 12 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — Fuel Transportation Agreement.”

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 contributions 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 assumed discount rate, changes in the funding

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regulations, and actual returns on fund assets. Cleco Power is the plan sponsor and Support Group is 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 and six months ended June 30, 2018, and 2017 were as follows:

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED JUNE 30,						FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018		2017
Components of periodic benefit costs
Service cost	$	2,361		$	2,295		$	338	$	385
Interest cost	5,472			5,467			357		402
Expected return on plan assets	(5,938		)	(5,895		)	—		—
Amortizations
Prior period service credit	(18		)	(18		)	—		—
Net loss (gain)	2,960			2,591			5		(2		)
Net periodic benefit cost	$	4,837		$	4,440		$	700	$	785

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE SIX MONTHS ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018		2017
Components of periodic benefit costs
Service cost	$	4,753		$	4,520		$	675	$	770
Interest cost	10,654			10,824			715		805
Expected return on plan assets	(11,875		)	(12,032		)	—		—
Amortizations
Prior period service credit	(36		)	(36		)	—		—
Net loss (gain)	5,921			5,004			10		(5		)
Net periodic benefit cost	$	9,417		$	8,280		$	1,400	$	1,570

Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2018, was $0.5 million and $1.0 million, respectively. The expense of the pension plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2017, was $0.5 million and $0.9 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 and six months ended June 30, 2018, was $0.8 million and $1.6 million, respectively. The expense related to Other Benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2017, was $0.9 million and $1.7 million, respectively. The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at June 30, 2018, and December 31, 2017, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	4,061	$	4,061
Non-current	$	38,270	$	39,142

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	3,525	$	3,525
Non-current	$	33,302	$	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

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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 the plan sponsor and Support Group is the plan administrator.

The non-service components of net periodic benefit cost related to SERP are included in Other expense within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. Net periodic benefit cost related to SERP for the three and six months ended June 30, 2018, and 2017 were as follows:

	FOR THE THREE MONTHS  ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018			2017
Components of periodic benefit costs
Service cost	$	166		$	102		$	271		$	247
Interest cost	1,004			820			1,764			1,620
Amortizations
Prior period service credit	(47		)	(29		)	(81		)	(68		)
Net loss	647			624			1,232			1,025
Net periodic benefit cost	1,770			1,517			3,186			2,824
Special/contractual termination benefits	—			—			—			315
Total benefit cost	$	1,770		$	1,517		$	3,186		$	3,139

There was a remeasurement of SERP in March 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 for the three and six months ended June 30, 2018, was $0.4 million and $0.7 million, respectively. The total expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2017, was $0.3 million and $0.6 million, respectively.

Liabilities relating to SERP are reported on the individual subsidiaries’ financial statements. The current and non-current portions of the SERP liability for Cleco and Cleco Power at June 30, 2018, and December 31, 2017, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	4,471	$	4,471
Non-current	$	79,487	$	79,868

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	929	$	929
Non-current	$	12,934	$	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 and six monthsended June 30, 2018, and 2017 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
401(k) Plan expense	$	1,229	$	1,204	$	3,292	$	2,872

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2018, and 2017 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
401(k) Plan expense	$	209	$	198	$	611	$	477

Note 8 — Income Taxes

Effective Tax Rates

The following tables summarize the effective income tax rates for Cleco and Cleco Power for the three and six months ended June 30, 2018, and 2017:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2018		2017		2018		2017
Effective tax rate	22.9	%	38.9	%	22.3	%	37.8	%

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2018		2017		2018		2017
Effective tax rate	24.2	%	39.2	%	23.9	%	38.1	%

For the three and six months ended June 30, 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.

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Uncertain Tax Positions

Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. At June 30, 2018, and December 31, 2017, Cleco and Cleco Power had no interest payable related to uncertain tax positions. For the six months ended June 30, 2018, and 2017, Cleco and Cleco Power had no interest expense related to uncertain tax positions.

At June 30, 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 June 30, 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 six months ended June 30, 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 of 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 has issued guidance which clarifies accounting for income taxes if information is not yet available or complete. The SEC 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 impacts of the TCJA also decreased the ADIT liability for Cleco and Cleco Power by $394.9 million and $362.9 million, respectively, at December

31, 2017. For the six months ended June 30, 2018, there were no adjustments in the ADIT liability related to the TCJA for Cleco or Cleco Power.

The impacts of the TCJA, 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 that any final adjustments to the provisional amounts will be recorded by the fourth quarter of 2018, which could have a material adverse effect on the results of operations of Cleco.

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 following tables 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 following tables 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.

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SEGMENT INFORMATION FOR THE THREE MONTHS ENDED JUNE 30,
2018 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	296,633		$	(2,420	)	$	—		$	294,213
Other operations	18,685			—			—			18,685
Electric customer credits	(13,637		)	—			—			(13,637		)
Affiliate revenue	220			17,273			(17,493		)	—
Operating revenue, net	$	301,901		$	14,853		$	(17,493	)	$	299,261
Depreciation and amortization	$	39,720		$	2,086		$	1		$	41,807
Interest charges	$	18,107		$	13,843		$	(41	)	$	31,909
Interest income	$	1,313		$	152		$	(38	)	$	1,427
Federal and state income tax expense (benefit)	$	13,710		$	(6,045	)	$	—		$	7,665
Net income (loss)	$	43,020		$	(17,182	)	$	1		$	25,839

2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	289,855		$	(2,420	)	$	—		$	287,435
Other operations	20,950			515			—			21,465
Electric customer credits	(239		)	—			—			(239		)
Affiliate revenue	221			13,631			(13,852		)	—
Operating revenue, net	$	310,787		$	11,726		$	(13,852	)	$	308,661
Depreciation and amortization	$	39,473		$	2,079		$	—		$	41,552
Interest charges	$	17,411		$	13,285		$	(75	)	$	30,621
Interest income	$	328		$	127		$	(74	)	$	381
Federal and state income tax expense (benefit)	$	23,063		$	(6,843	)	$	—		$	16,220
Net income (loss)	$	35,733		$	(10,289	)	$	—		$	25,444

SEGMENT INFORMATION FOR THE SIX MONTHS ENDED JUNE 30,
2018 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	561,264		$	(4,840	)	$	—		$	556,424
Other operations	40,880			1			—			40,881
Electric customer credits	(21,284		)	—			—			(21,284		)
Affiliate revenue	428			32,942			(33,370		)	—
Operating revenue, net	$	581,288		$	28,103		$	(33,370	)	$	576,021
Depreciation and amortization	$	80,109		$	4,205		$	—		$	84,314
Interest charges	$	35,763		$	27,392		$	(88	)	$	63,067
Interest income	$	1,953		$	342		$	(84	)	$	2,211
Federal and state income tax expense (benefit)	$	21,707		$	(11,180	)	$	1		$	10,528
Net income (loss)	$	69,024		$	(32,324	)	$	—		$	36,700
Additions to property, plant, and equipment	$	135,334		$	368		$	—		$	135,702
Equity investment in investees (1)	$	18,172		$	—		$	—		$	18,172
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,807,559		$	599,216		$	(21,164	)	$	6,385,611
(1) Balances as of June 30, 2018

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2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	527,408		$	(5,917	)	$	—		$	521,491
Other operations	37,315			1,030						38,345
Electric customer credits	(674		)	—			—			(674		)
Affiliate revenue	440			28,365			(28,805		)	—
Operating revenue, net	$	564,489		$	23,478		$	(28,805	)	$	559,162
Depreciation and amortization	$	78,230		$	4,172		$	—		$	82,402
Interest charges	$	35,515		$	26,966		$	(142	)	$	62,339
Interest income	$	594		$	240		$	(141	)	$	693
Federal and state income tax expense (benefit)	$	32,918		$	(13,591	)	$	—		$	19,327
Net income (loss)	$	53,587		$	(21,851	)	$	—		$	31,736
Additions to property, plant, and equipment	$	127,297		$	1,396		$	—		$	128,693
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

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 ofJune 30, 2018,Cleco Power had $2.1 million accrued 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. Cleco Power responded to three sets of data requests from the LPSC for the 2017 monitoring report. On June 5, 2018, the LPSC filed its review of the 2017 FRP monitoring report which identified two exceptions; however, it concurred that no earnings-related refunds were due. Cleco Power filed a response to the review report on July 6, 2018, and anticipates filing a joint report for LPSC approval in the third quarter 2018. As of June 30, 2018, Cleco Power had $1.2 million accrued for the cost of service savings refund for the June 30, 2017 FRP monitoring report. Cleco Power expects to file its monitoring report for the 12 months ended June 30, 2018, on or before October 31, 2018, which will indicate that

$5.9 million of earnings-related refunds and $1.2 million of cost of service savings refunds are due to be returned to eligible customers. These amounts were accrued at June 30, 2018.

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 in the third 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 was 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 June 30, 2018, Cleco Power had $4.4 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

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settlement conference was held on February 22, 2018; however, a settlement was not reached. On May 14, 2018, the settlement judge terminated the settlement proceedings. A hearing is scheduled for January 2019 with an initial decision from the ALJ expected in May 2019. 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. At June 30, 2018, Cleco Power had $14.7 million accrued for the estimated federal tax-related benefits from the TCJA. Cleco Power anticipates filing an application with the LPSC no later than August 31, 2018, for consideration of Cleco Power’s methodology for TCJA refunds and related items, including the allocation of such refunds among Cleco Power’s jurisdictional customers. Rates are anticipated to go into effect October 1, 2018. Cleco Power anticipates refunding the amount accrued for the change in the tax rate for the period January 2018 to September 2018 on customers’ September 2018 bills, based on July 2018 usage, pending LPSC review and approval. Cleco Power expects to address the regulatory liability for excess ADIT resulting from the enactment of the TCJA in Cleco Power’s application for its new FRP, which will be filed by June 30, 2019, with anticipated new rates being effective July 1, 2020.

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 June 30, 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 JUNE 30, 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 JUNE 30, 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 JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
Operating revenue	$	1,057	$	532	$	1,920	$	1,605
Operating expenses	1,057		532		1,920		1,605
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.

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

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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, BCI, 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 and May 2016, the plaintiffs filed their Third Consolidated Amended Verified Derivative Petition for Damages and Preliminary and Permanent Injunction and their Fourth Verified Consolidated Amended Class Action Petition,

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respectively. The fourth 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 in September 2016, and 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. In January 2018, Cleco filed a writ with the Louisiana Supreme Court seeking review of the Third Circuit Court of Appeal’s decision. The writ was denied in March 2018. 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 briefing on Cleco Power’s motion is now complete, but the district court has not ruled on the motion or set a hearing date.

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. 18-cv-153, U.S. District Court for the Eastern District of Texas. The allegations are essentially identical to those in the BoninCase. On April 13, 2018, Cleco Power filed a motion to dismiss on the same grounds that previously were successful in the Bonin Case. The briefing on Cleco Power’s motion is complete, but the district court has not ruled on the motion or set a hearing date. On July 20, 2018, the district court entered an order consolidating the Addison Case with the Bonin Case. 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. Cleco Power has responded to two sets of data requests. Periods subsequent to December 31, 2017, are also subject to audit. 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

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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. On May 22, 2018, Cleco Power received notice of an EAC audit from the LPSC for the period of January 1, 2016 to December 31, 2017. The total amount of environmental expense included in the audit is $30.7 million. Cleco Power has responded to one set of data requests. Periods subsequent to December 31, 2017, are also subject to audit. 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 environmental 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.

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

Generally, Cleco Power records wholesale transmission revenue through Attachment O of the MISO tariff and certain grandfathered agreements. These rates are subject to periodic audits by FERC. 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 of January 1, 2014, to the present. Management has met with the auditors to discuss the progress of the audit. On July 31, 2018, Cleco Power received its first set of data requests related to this audit. 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 June 30, 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 June 30, 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 standby letters of credit, in order to facilitate their activities and the activities of Cleco Holdings’ subsidiaries and equity investees (affiliates). Cleco Holdings and Cleco Power have also agreed to contractual terms that require the Registrants to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees.

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

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

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

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

Cleco Holdings provided indemnifications to Cleco Power as a result of the transfer of Coughlin to Cleco Power in March 2014. Cleco Power also provided indemnifications to Cleco Holdings and Evangeline as a result of the transfer of Coughlin to Cleco Power. The maximum amount of the potential payment to Cleco Power, Cleco Holdings, and Evangeline for their respective indemnifications is $40.0 million, except for indemnifications relating to the fundamental organizational structure of each respective entity, of which the maximum amount is $400.0 million. Management does not expect to be required to make any payments under these indemnifications.

As part of the Amended Lignite Mining Agreement, Cleco Power and SWEPCO, joint owners of 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 June 30, 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 is being recognized over a ten-year period, which is projected to be completed by the end of 2018. 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. From September 2017 until April 2, 2018, Cleco Power had an operating lease that automatically renewed on a month-to-month basis for use of the 42 barges. On April 2, 2018, Cleco Power loaned Savage Inland Marine $16.8 million to purchase the barges. Also on April 2, 2018, 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.

Under the 2018 agreement, the barge lease rate contains both a fixed and variable component of which the latter will be adjusted every third anniversary of the new agreement for estimated executory costs. If the barges are idle, the lessor is required to attempt to sublease the barges to third parties with the revenue reducing Cleco Power’s lease payment. For the three and six months ended June 30, 2018, Cleco Power paid approximately $0.7 million in lease payments and received $0.1 million of revenue from subleases.

This agreement contains a provision for early termination upon the occurrence of any one of four cancellation events.

The following is an analysis of the leased property under Cleco Power’s capital lease:

(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Barges	$	16,800	$	—
Less: accumulated amortization	280		—
Net capital lease	$	16,520	$	—

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The following is a schedule by years of future minimum lease payments under the capital lease together with the present value of the net minimum lease payments as of June 30, 2018:

	(THOUSANDS)
Six months ending Dec. 31, 2018	$	1,306
Years ending Dec. 31,
2019	2,611
2020	2,611
2021	2,611
2022	2,611
2023	2,611
Thereafter	23,654
Total minimum lease payments	38,015
Less: executory costs	6,021
Net minimum lease payments	31,994
Less: amount representing interest	15,318
Present value of net minimum lease payments	$	16,676
Current liabilities	$	529
Non-current liabilities	$	16,147

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 long-term issuer credit rating on review for downgrade and affirmed Cleco Power at A3 (stable). Also on February 7, 2018, taking into consideration the pending NRG South Central acquisition, S&P affirmed Cleco Holdings’ and Cleco Power’s corporate 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. On May 11, 2018, taking into consideration the pending NRG South Central acquisition, Fitch assigned a first-time long-term issuer default rating of BBB- at Cleco Holdings and BBB at Cleco Power. If Cleco Holdings’ or Cleco Power’s credit ratings were to be downgraded Cleco Holdings or Cleco Power could be required to pay additional fees and incur higher interest rates for borrowings under their respective credit facilities. On July 31, 2018, Cleco amended its $300.0 million bank term loan agreement and its $100.0 million revolving credit facility agreement to release any and all collateral from all of its debt obligations under those agreements. As a result of the release of collateral, Cleco Holdings expects Moody’s and Fitch to update Cleco Holdings’ senior debt rating.

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 higher LMPs. 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.

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 JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	212	$	129	$	743	$	113
Support Group	486		10,572		608		8,582
Other (1)	—		—		4		2
Total	$	698	$	10,701	$	1,355	$	8,697
(1) Represents Attala and Perryville.

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 and six months ended June 30, 2018, Cleco Katrina/Rita recognized amortization expense of $5.5 million and $10.0 million, respectively, based on actual collections. During the three and six months ended June 30, 2017, Cleco Katrina/Rita recognized amortization expense of $4.7 million and $8.2 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 and six months ended June 30, 2018, Cleco recognized amortization expense of less than $0.1 million and $0.1 million, respectively, on the trade name intangible asset. During the three and six months ended June 30, 2017, Cleco recognized amortization expense of less than $0.1 million and $0.1 million, respectively, 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 and six months ended June 30, 2018, Cleco recognized a reduction of revenue of $2.4 million, and $4.8 million, respectively, on the intangible assets for the power supply agreements. During the three and six months ended June 30, 2017, Cleco recognized a reduction of

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revenue of $2.4 million and $6.0 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 June 30, 2018, and December 31, 2017:

Cleco
(THOUSANDS)	AT JUNE 30, 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	(60,909		)	(45,948		)
Net intangible assets subject to amortization	$	99,889		$	114,850

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018			AT DEC. 31, 2017
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	177,537		$	177,537
Accumulated amortization	(145,830		)	(135,836		)
Net intangible assets subject to amortization	$	31,707		$	41,701

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 JUNE 30, 2018			FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(2,878	)	$	(2,921	)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	247			290
Net current-period other comprehensive income	247			290
Balances, June 30, 2018	$	(2,631	)	$	(2,631	)

	FOR THE THREE MONTHS ENDED JUNE 30, 2017			FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(691	)	$	1,500
Other comprehensive income (loss) before reclassifications
Postretirement benefits adjustment during the period	—			(2,065		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss (gain)	60			(66		)
Net current-period other comprehensive income (loss)	60			(2,131		)
Balances, June 30, 2017	$	(631	)	$	(631	)

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2018									FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI			POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(8,144	)	$	(5,242	)	$	(13,386	)	$	(8,377	)	$	(5,306	)	$	(13,683	)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	267			—			267			500			—			500
Reclassification of net loss to interest charges	—			64			64			—			128			128
Net current-period other comprehensive income	267			64			331			500			128			628
Balances, June 30, 2018	$	(7,877	)	$	(5,178	)	$	(13,055	)	$	(7,877	)	$	(5,178	)	$	(13,055	)

	FOR THE THREE MONTHS ENDED JUNE 30, 2017									FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI			POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(8,325	)	$	(5,464	)	$	(13,789	)	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive income (loss) before reclassifications
Postretirement benefit adjustments during the period	—			—			—			(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	193			—			193			357			—			357
Reclassification of net loss to interest charges	—			53			53			—			106			106
Net current-period other comprehensive income (loss)	193			53			246			(227		)	106			(121		)
Balances, June 30, 2017	$	(8,132	)	$	(5,411	)	$	(13,543	)	$	(8,132	)	$	(5,411	)	$	(13,543	)

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

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 by FERC, the LPSC, the Public Utility Commission of Texas, and final approval from the Federal Communications Commission (FCC). On February 27, 2018, Cleco filed a joint application seeking approval of the transaction with FERC. 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 the Public Utility Commission of Texas seeking approval of the transaction. On June 19, 2018, the Committee on Foreign Investment in the United States approved and cleared Cleco’s application for the transaction to proceed. On July 10, 2018, the FCC’s consent to transfer two of three licenses to Cleco

Cajun became final. The FCC’s consent to transfer the third license is expected to become final on August 7, 2018. Cleco is in the process of responding to data requests from the LPSC staff for the LPSC application.

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.

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

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

The following discussion and analysis should be read in combination with the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017, and Cleco and Cleco Power’s Condensed Consolidated Financial Statements contained in this Combined Quarterly Report on Form 10-Q. The information included therein is essential to understanding the following discussion and analysis. Below is information concerning the consolidated results of operations of Cleco for the three and six months ended June 30, 2018, and 2017.

OVERVIEW

Cleco is a regional energy company that conducts substantially all of its business operations through its primary subsidiary, Cleco Power. Cleco Power is a regulated electric

utility company that owns nine generating units with a total nameplate capacity of 3,310 MW and serves approximately 290,000 customers in Louisiana through its retail business and supplies wholesale power in Louisiana and Mississippi.

Plan of Acquisition

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 Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 16 — Plan of Acquisition.”

Cleco Power

Many factors affect Cleco Power’s primary business of generating, delivering, and selling electricity. These factors include weather and the presence of a stable regulatory environment, which impacts cost recovery and the ROE, as well as the recovery of costs related to growing energy demand and rising fuel prices; the ability to increase energy sales while containing costs; the ability to reliably deliver

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

power to its jurisdictional customers; the ability to comply with increasingly stringent regulatory and environmental standards; and the ability to successfully perform in MISO while subject to the related operating challenges and uncertainties, including increased wholesale competition. Key initiatives on which Cleco Power is currently working include continuing construction on the St. Mary Clean Energy Center project and the Terrebonne to Bayou Vista Transmission project; initiating construction of the Coughlin Pipeline project; continuing the START project; and maintaining and growing its wholesale and retail business. These initiatives are discussed below.

St. Mary Clean Energy Center Project

The St. Mary Clean Energy Center project includes Cleco Power constructing, owning, and operating a 50-MW generating unit to be fueled by waste heat from Cabot Corporation’s carbon black manufacturing plant in Franklin, Louisiana. Construction began in October 2016 and the unit is expected to be commercially operational in the fourth quarter of 2018 at an estimated cost of $113.6 million. The project is expected to generate more than 300,000 MWh of zero additional carbon emitting energy each year. As of June 30, 2018, Cleco Power had spent $94.1 million on the project.

Terrebonne to Bayou Vista Transmission Project

The Terrebonne to Bayou Vista Transmission project includes the construction of additional transmission interconnection facilities south of Teche Power Station. The project is expected to increase reliability, reduce congestion, and provide hurricane hardening of the 230-kilovolt transmission system for customers in south Louisiana. Cleco Power’s portion of the joint project with Entergy Louisiana is expected to cost $64.3 million. Construction began in July 2018 and is expected to be complete in the third quarter of 2019. As of June 30, 2018, Cleco Power had spent $22.7 million on the project.

Coughlin Pipeline Project

The Coughlin Pipeline project includes construction of a pipeline directly connecting the Pine Prairie Energy Center to Cleco’s Coughlin Power Station. The project is expected to increase reliability for fuel delivery and mitigate exposure to transportation cost increases. In June 2017, the LPSC approved the establishment of a regulatory asset for the revenue requirement associated with the Coughlin Pipeline project until Cleco Power seeks recovery in the new FRP, which is anticipated to be effective July 1, 2020. The project is expected to be complete in the third quarter of 2019 with an estimated cost of $32.1 million. As of June 30, 2018, Cleco Power had spent $3.0 million on the project.

START Project

The START project includes replacement of and improvement to Cleco’s enterprise business applications. The project’s objectives are to gain efficiencies through consistent, industry-leading work processes and practices; enable better decision making through data transparency across business functions; mitigate risk through knowledge transfer and better process documentation; provide a modernized, flexible platform to support future growth and changing business models; and provide customer-centric focus through technology and flexibility. The project is at the end of the build phase and is transitioning to the testing phase. Management expects the project to be complete in the third quarter of 2019. The total

estimated project cost is $136.5 million. As of June 30, 2018, Cleco had spent $73.5 million on the project.

Other

Cleco Power is working to secure load growth opportunities that include renewing existing franchises and wholesale contracts, pursuing new wholesale contracts and franchises, and adding new retail load opportunities with large industrial, commercial, and residential load. The retail opportunities include sectors such as agriculture, oil and gas, chemicals, metals, national accounts, government and military, wood and paper, health care, information technology, transportation, and other manufacturing.

RESULTS OF OPERATIONS

Comparison of the Three Months Ended June 30, 2018, and 2017

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2018		2017		VARIANCE			CHANGE
Operating revenue, net	$	299,261	$	308,661	$	(9,400	)	(3.0	)%
Operating expenses	235,552		235,391		(161		)	(0.1	)%
Operating income	$	63,709	$	73,270	$	(9,561	)	(13.0	)%
Interest income	$	1,427	$	381	$	1,046		274.5	%
Allowance for equity funds used during construction	$	3,224	$	1,440	$	1,784		123.9	%
Interest charges	$	31,909	$	30,621	$	(1,288	)	(4.2	)%
Federal and state income tax expense	$	7,665	$	16,220	$	8,555		52.7	%
Net income	$	25,839	$	25,444	$	395		1.6	%

Operating revenue, net decreased $9.4 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to higher electric customer credits, lower other operations revenue, and lower fuel cost recovery revenue, partially offset by higher base revenue at Cleco Power.

Operating expenses increased $0.2 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to NRG South Central acquisition transaction expenses at Cleco Holdings. This increase was partially offset by lower recoverable and non-recoverable fuel and power purchased expenses, lower other operations expenses, and lower taxes other than income taxes at Cleco Power.

Interest income increased $1.0 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to higher interest rates and balances on temporary investments and interest on other long-term receivables at Cleco Power.

Allowance for equity funds used during construction increased $1.8 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to higher costs related to the St. Mary Clean Energy Center project, the START project, and the Terrebonne to Bayou Vista Transmission project.

Interest charges increased $1.3 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to long-term debt issued in December 2017 and March 2018 at Cleco Power and higher variable interest rates on the bank term loan at Cleco Holdings. These increases

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

were partially offset by an increase in allowance for borrowed funds used during construction and lower interest on Cleco Katrina/Rita storm recovery bonds due to the repayment of the first tranche of the bonds in March 2017.

Federal and state income tax expense decreased $8.6 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to $3.8 million for the change in pretax income, excluding AFUDC equity, $3.2 million for adjustments related to the reduction in the federal statutory tax rate prescribed by the TCJA, $0.6 million for tax credits, $0.4 million for adjustments for permanent tax differences, $0.4 million for the flowthrough of state tax benefits, and $0.2 million to record tax expense at the consolidated projected annual effective tax rate.

The effective income tax rate for the second quarter of 2018 and 2017 was 22.9% and 38.9%, respectively. The estimated annual effective income tax rate used during the second quarter of 2018 and 2017 for Cleco may not be indicative of the full-year income tax rate.

Results of operations for Cleco Power are more fully described below.

Cleco Power
				FOR THE THREE MONTHS ENDED JUNE 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2018			2017				VARIANCE			CHANGE
Operating revenue
Base	$	177,354		$	168,150			$	9,204		5.5	%
Fuel cost recovery	119,279			121,705				(2,426		)	(2.0	)%
Electric customer credits	(13,637		)	(239		)		(13,398		)	*
Other operations	18,685			20,950				(2,265		)	(10.8	)%
Affiliate revenue	220			221				(1		)	(0.5	)%
Operating revenue, net	301,901			310,787				(8,886		)	(2.9	)%
Operating expenses
Recoverable fuel and power purchased	119,278			121,707				2,429			2.0	%
Non-recoverable fuel and power purchased	8,438			9,623				1,185			12.3	%
Other operations	26,812			27,649				837			3.0	%
Maintenance	24,138			24,264				126			0.5	%
Depreciation and amortization	39,720			39,473				(247		)	(0.6	)%
Taxes other than income taxes	10,913			11,404				491			4.3	%
Total operating expenses	229,299			234,120				4,821			2.1	%
Operating income	$	72,602		$	76,667			$	(4,065	)	(5.3	)%
Interest income	$	1,313		$	328			$	985		300.3	%
Allowance for equity funds used during construction	$	3,224		$	1,440			$	1,784		123.9	%
Interest charges	$	18,107		$	17,411			$	(696	)	(4.0	)%
Federal and state income tax expense	$	13,710		$	23,063			$	9,353		40.6	%
Net income	$	43,020		$	35,733			$	7,287		20.4	%
* Not meaningful

Cleco Power’s net income in the second quarter of 2018 increased $7.3 million compared to the second quarter of 2017 primarily as a result of the following factors:

• lower federal and state income tax expense,

• higher base revenue,

• higher allowance for equity funds used during construction, and

• lower non-recoverable fuel and power purchased.

These increases were partially offset by:

• higher electric customer credits and

• lower other operations revenue.

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

	FOR THE THREE MONTHS ENDED JUNE 30,
(MILLION kWh)	2018	2017	FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	943	868		8.6	%
Commercial	704	671		4.9	%
Industrial	572	506		13.0	%
Other retail	32	33		(3.0	)%
Total retail	2,251	2,078		8.3	%
Sales for resale	750	702		6.8	%
Total retail and wholesale customer sales	3,001	2,780		7.9	%

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

	FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	80,336	$	73,880		8.7	%
Commercial	49,787		48,234			3.2	%
Industrial	22,704		22,369			1.5	%
Other retail	2,721		2,687			1.3	%
Surcharge	6,193		5,651			9.6	%
Total retail	161,741		152,821			5.8	%
Sales for resale	15,613		15,329			1.9	%
Total base revenue	$	177,354	$	168,150		5.5	%

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

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

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

	FOR THE THREE MONTHS ENDED JUNE 30,
				2018 CHANGE
	2018	2017	NORMAL	PRIOR YEAR		NORMAL
Cooling degree-days	1,058	924	942	14.5	%	12.3	%

Base

Base revenue increased $9.2 millionduring the second quarter of 2018 compared to the second quarter of 2017 primarily due to $8.2 million related to higher usage from warmer summer weather and $1.0 million due to higher rates primarily as a result of the annual FRP rate adjustment.

For information on the effects of future energy sales on the results of operations, financial condition, or cash flows of Cleco Power, see Part I, Item 1A, “Risk Factors — Future Electricity Sales” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Fuel Cost Recovery/Recoverable Fuel and Power Purchased

Changes in fuel costs historically have not significantly affected Cleco Power’s net income. Generally, fuel and purchased power expenses are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such charges. Approximately 78% of Cleco Power’s total fuel cost during the second quarter of 2018 was regulated by the LPSC. Recovery of FAC costs is subject to periodic fuel audits by the LPSC which may result in a refund to customers. Generally, fuel and purchased power expenses are impacted by customer usage, the per unit cost of fuel used for electric generation, and the dispatch of Cleco Power’s generating facilities by MISO. Fuel and purchased power expenses were also impacted by the interruption of the continuous supply of lignite due to adverse weather conditions and other factors that disrupted mining operations and transportation to Dolet Hills Power Station. For more information on fuel audits, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Fuel Audit.”

Electric Customer Credits

Electric customer credits increased $13.4 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to $7.3 million of accrued estimated refunds for the federal tax-related benefits for the TCJA, $5.9 million of accrued estimated refunds for the June 2018 FRP monitoring report, and $0.2 million for higher accruals for site-specific customers. For more information on the TCJA, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 8 — Income Taxes.” For more information on the FRP, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 10 — Regulation and Rates.”

Other Operations Revenue

Other operations revenue decreased $2.3 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to $2.4 million of lower net generation revenue from SSR payments, $0.7 million of lower transmission revenue due to pass-through of MISO credits to a wholesale customer, and $0.3 million of higher amortization of the emergency declarations regulatory asset. These decreases were partially offset by $0.7 million of higher net transmission

and distribution revenue, $0.2 million of higher reconnect fees, and $0.2 million of higher miscellaneous revenue. For more information on the SSR, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 10 — Regulation and Rates — SSR.”

Non-recoverable Fuel and Power Purchased

Non-recoverable fuel and power purchased decreased $1.2 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to $0.7 million of lower MISO transmission expenses due to MISO credits, $0.3 million of lower miscellaneous expenses, $0.2 million of lower MISO transmission expenses primarily due to lower rates, and $0.2 million of lower MISO SSR net transmission expenses. These decreases were partially offset by $0.2 million for amortization of the regulatory asset related to the retail portion of the insurance deductible for flood damages. For more information on the SSR, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 10 — Regulation and Rates — SSR.”

Interest Income

Interest income increased $1.0 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to $0.5 million of higher interest rates and balances on temporary investments, $0.4 million of interest on other long-term receivables, and $0.1 million of higher miscellaneous interest income.

Allowance for Equity Funds Used During Construction

Allowance for equity funds used during construction increased $1.8 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to higher costs related to the St. Mary Clean Energy Center project, the START project, and the Terrebonne to Bayou Vista Transmission project.

Interest Charges

Interest charges increased $0.7 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to $1.3 million of interest on long-term debt from senior notes issued in December 2017 and March 2018 and $0.3 million of interest on the accrued estimated refunds for the federal tax-related benefits for the TCJA. These increases were partially offset by $0.6 million of higher allowance for borrowed funds used during construction and $0.3 million of lower interest on Cleco Katrina/Rita storm recovery bonds due to the repayment of the first tranche of the bonds in March 2017.

Income Taxes

Federal and state income tax expense decreased $9.4 million during the second quarter of 2018 compared to the second quarter of 2017 primarily due to $6.1 million for adjustments related to the reduction in the federal statutory rate prescribed by the TCJA, $1.5 million for the change in pretax income, excluding AFUDC equity, $1.0 million to record tax expense at the projected annual effective tax rate, $0.5 million for adjustments for permanent tax differences, and $0.3 million for the flowthrough of state tax benefits.

The effective income tax rate for the second quarter of 2018 and 2017 was 24.2% and 39.2%, respectively. The estimated annual effective income tax rate used during the second quarter of 2018 and 2017 for Cleco Power may not be indicative of the full-year income tax rate.

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CLECO POWER	2018 2ND QUARTER FORM 10-Q

Comparison of the Six Months Ended June 30, 2018, and 2017

Cleco
	FOR THE SIX MONTHS ENDED JUNE 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2018			2017			VARIANCE			CHANGE
Operating revenue, net	$	576,021		$	559,162		$	16,859		3.0	%
Operating expenses	467,577			444,429			(23,148		)	(5.2	)%
Operating income	$	108,444		$	114,733		$	(6,289	)	(5.5	)%
Interest income	$	2,211		$	693		$	1,518		219.0	%
Allowance for equity funds used during construction	$	5,587		$	2,350		$	3,237		137.7	%
Other expense, net	$	(5,947	)	$	(4,374	)	$	(1,573	)	(36.0	)%
Federal and state income tax expense	$	10,528		$	19,327		$	8,799		45.5	%
Net income	$	36,700		$	31,736		$	4,964		15.6	%

Operating revenue, net increased $16.9 million during the first six months of 2018 compared to the first six months of 2017 primarily due to higher base revenue, higher fuel cost recovery revenue, and higher other operations revenue, partially offset by higher electric customer credits at Cleco Power.

Operating expenses increased $23.1 million during the first six months of 2018 compared to the first six months of 2017 primarily due to higher recoverable and non-recoverable fuel and power purchased expenses, higher generation maintenance expenses, higher depreciation and amortization at Cleco Power, and NRG South Central acquisition transaction expenses at Cleco Holdings. These increases were partially offset by lower other operations expense at Cleco Power.

Interest income increased $1.5 million during the first six months of 2018 compared to the first six months of 2017 primarily due to higher interest rates and balances on temporary investments and interest on other long-term receivables at Cleco Power.

Allowance for equity funds used during construction increased $3.2 million during the first six months of 2018 compared to the first six months of 2017 primarily due tohigher costs related to the St. Mary Clean Energy Center project, the START project, and the Terrebonne to Bayou Vista Transmission project.

Other expense, net increased $1.6 million during the first six months of 2018 compared to the first six months of 2017 primarily due to the decrease in cash surrender value of life insurance policies due to unfavorable market conditions at Cleco Holdings and higher non-service costs of postretirement benefits at Cleco Power, partially offset by higher royalty income at Cleco Power.

Federal and state income tax expense decreased $8.8 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $3.8 million for adjustments related to the reduction in the federal statutory tax rate prescribed by the TCJA, $2.7 million for the change in pretax income, excluding AFUDC equity, $1.7 million for the flowthrough of state tax benefits, $0.9 million for adjustments for permanent tax differences, and $0.6 million for adjustments for tax credits. These decreases were partially offset by $0.9 million to record tax expense at the consolidated projected annual effective tax rate.

The effective income tax rate for the six months ended June 30, 2018, and 2017 was 22.3% and 37.8%, respectively. The estimated annual effective income tax rate used during the

six months ended June 30, 2018, and 2017 for Cleco might not be indicative of the full-year income tax rate.

Results of operations for Cleco Power are more fully described below.

Cleco Power
				FOR THE SIX MONTHS ENDED JUNE 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2018			2017			VARIANCE			CHANGE
Operating revenue
Base	$	331,675		$	311,268		$	20,407		6.6	%
Fuel cost recovery	229,589			216,140			13,449			6.2	%
Electric customer credits	(21,284		)	(674		)	(20,610		)	*
Other operations	40,880			37,315			3,565			9.6	%
Affiliate revenue	428			440			(12		)	(2.7	)%
Operating revenue, net	581,288			564,489			16,799			3.0	%
Operating expenses
Recoverable fuel and power purchased	229,588			215,987			(13,601		)	(6.3	)%
Non-recoverable fuel and power purchased	18,303			17,179			(1,124		)	(6.5	)%
Other operations	54,116			57,913			3,797			6.6	%
Maintenance	53,216			48,684			(4,532		)	(9.3	)%
Depreciation and amortization	80,109			78,230			(1,879		)	(2.4	)%
Taxes other than income taxes	22,831			23,404			573			2.4	%
Total operating expenses	458,163			441,397			(16,766		)	(3.8	)%
Operating income	$	123,125		$	123,092		$	33		—	%
Interest income	$	1,953		$	594		$	1,359		228.8	%
Allowance for equity funds used during construction	$	5,587		$	2,350		$	3,237		137.7	%
Interest charges	$	35,763		$	35,515		$	(248	)	(0.7	)%
Federal and state income tax expense	$	21,707		$	32,918		$	11,211		34.1	%
Net income	$	69,024		$	53,587		$	15,437		28.8	%
* Not meaningful

Cleco Power’s net income in the first six months of 2018 increased $15.4 million compared to the first six months of 2017 primarily as a result of the following factors:

• higher base revenue,

• lower federal and state income tax expense,

• lower other operations expense,

• higher other operations revenue,

• higher allowance for equity funds used during construction, and

• higher interest income.

These increases were partially offset by:

• higher electric customer credits,

• higher maintenance expense,

• higher depreciation and amortization, and

• higher non-recoverable fuel and power purchased.

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

	FOR THE SIX MONTHS ENDED JUNE 30,
(Million kWh)	2018	2017	FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	1,801	1,578		14.1	%
Commercial	1,316	1,256		4.8	%
Industrial	1,079	995		8.4	%
Other retail	66	64		3.1	%
Total retail	4,262	3,893		9.5	%
Sales for resale	1,422	1,331		6.8	%
Total retail and wholesale customer sales	5,684	5,224		8.8	%

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

	FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	143,114	$	128,907		11.0	%
Commercial	97,251		93,701			3.8	%
Industrial	44,628		43,088			3.6	%
Other retail	5,462		5,248			4.1	%
Surcharge	11,431		10,734			6.5	%
Total retail	301,886		281,678			7.2	%
Sales for resale	29,789		29,590			0.7	%
Total base revenue	$	331,675	$	311,268		6.6	%

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

			FOR THE SIX MONTHS ENDED JUNE 30,
				2018 CHANGE
	2018	2017	NORMAL	PRIOR YEAR		NORMAL
Heating degree-days	881	440	940	100.2	%	(6.3	)%
Cooling degree-days	1,257	1,156	1,020	8.7	%	23.2	%

Base

Base revenue increased $20.4 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $18.8 million related to higher usage from colder winter weather and warmer summer weather and $1.6 million due to higher rates primarily as a result of the annual FRP rate adjustment.

For information on the effects of future energy sales on the results of operations, financial condition, or cash flows of Cleco Power, see Part I, Item 1A, “Risk Factors — Future Electricity Sales” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Fuel Cost Recovery/Recoverable Fuel and Power Purchased

Changes in fuel costs historically have not significantly affected Cleco Power’s net income. Generally, fuel and purchased power expenses are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such charges. Approximately 76% of Cleco Power’s total fuel cost during the first six months of

2018 was regulated by the LPSC. Recovery of FAC costs is subject to periodic fuel audits by the LPSC which may result in a refund to customers. Generally, fuel and purchased power expenses are impacted by customer usage, the per unit cost of fuel used for electric generation, and the dispatch of Cleco Power’s generating facilities by MISO. Fuel and purchased power expenses were also impacted by the interruption of the continuous supply of lignite due to adverse weather conditions and other factors that disrupted mining operations and transportation to Dolet Hills Power Station. For more information on fuel audits, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Fuel Audit.”

Electric Customer Credits

Electric customer credits increased $20.6 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $14.7 million of accrued estimated refunds for the federal tax-related benefits for the TCJA and $5.9 million of accrued estimated refunds for the June 2018 FRP monitoring report. For more information on the TCJA, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 8 — Income Taxes.” For more information on the FRP, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 10 — Regulation and Rates.”

Other Operations Revenue

Other operations revenue increased $3.6 million during the first six months of 2018 compared to the first six months of 2017 primarily related to $2.3 million of higher revenue from wholesale customers due to the absence of issuing customer credits relating to the MISO ROE complaints, $1.4 million of higher net transmission and distribution revenue, $0.8 million of higher net generation revenue from SSR payments, $0.6 million of higher reconnect fees, and $0.3 million of higher miscellaneous revenue. These increases were partially offset by $1.3 million of lower transmission revenue due to pass-through of MISO credits to a wholesale customer and $0.5 million of higher amortization of the emergency declarations regulatory asset. For more information on the SSR, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 10 — Regulation and Rates — SSR.”

Non-recoverable Fuel and Power Purchased

Non-recoverable fuel and power purchased increased $1.1 million during the first six months of 2018 compared to the first six months of 2017 primarily due to the absence of a $2.3 million refund from MISO for wholesale customers relating to the MISO ROE complaints, $1.1 million of higher MISO SSR net transmission expenses, and $0.4 million for amortization of the regulatory asset related to the retail portion of the insurance deductible for flood damages. These increases were partially offset by $1.3 million of lower MISO transmission expenses primarily due to MISO credits, $1.1 million of lower MISO transmission expenses primarily due to lower rates, and $0.3 million of lower miscellaneous expenses.

Other Operations Expense

Other operations expense decreased $3.8 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $5.2 million of lower compensation

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expenses, $1.7 million for the absence of the write-off of an uncollectible account, $0.9 million of lower customer service expenses, $0.6 million for lower uncollectible accounts, and $0.2 million of the flood related uncollectible accounts deferred to regulatory assets. These decreases were partially offset by $2.0 million of higher generation operations expense, $1.0 million of higher distribution operations expense, $0.9 million of higher employee benefits expenses, $0.6 million of higher fees for outside services, and $0.3 million for higher miscellaneous expenses.

Maintenance Expense

Maintenance expense increased $4.5 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $5.7 million of higher net generating station outage and routine maintenance expenses and $0.6 million of higher routine transmission maintenance expenses. These increases were partially offset by $0.9 million of lower routine distribution maintenance expenses, $0.8 million of lower administrative and general maintenance expenses, and $0.1 million of lower miscellaneous expenses.

Depreciation and Amortization

Depreciation and amortization expense increased $1.9 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $2.0 million of normal recurring additions to fixed assets and $1.8 million of higher amortization of storm damages, which is based on collections from customer. These increases were partially offset by $0.7 million of higher deferrals of corporate franchise taxes to regulatory assets, $0.7 million of lower amortization of a regulatory asset related to state corporate franchise taxes, and $0.5 million of lower miscellaneous amortization.

Interest Income

Interest income increased $1.4 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $0.8 million of higher interest rates and balances on temporary investments, $0.4 million of interest on other long-term receivables, and $0.2 million of higher miscellaneous interest income.

Allowance for Equity Funds Used During Construction

Allowance for equity funds used during construction increased $3.2 million during the first six months of 2018 compared to the first six months of 2017 primarily due to higher costs related to the St. Mary Clean Energy Center project, the START project, and the Terrebonne to Bayou Vista Transmission project.

Interest Charges

Interest charges increased $0.2 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $2.3 million of interest on long-term debt from senior notes issued in December 2017 and March 2018 and $0.3 million of interest on the accrued estimated refunds for the federal tax-related benefits for the TCJA. These increases were partially offset by $1.3 million of higher allowance for borrowed funds used during construction, $0.5 million of lower interest on Cleco Katrina/Rita storm recovery bonds, $0.5 million for the absence of the debt discount write-off on the first tranche of the Cleco Katrina/Rita storm recovery bonds that was repaid in March 2017, and $0.1 million of lower miscellaneous expenses.

Income Taxes

Federal and state income tax expense decreased $11.2 million during the first six months of 2018 compared to the first six months of 2017 primarily due to $9.2 million for adjustments related to the reduction in the federal statutory tax rate prescribed by the TCJA, $1.7 million for the flowthrough of state tax benefits, and $1.0 million for adjustments for permanent tax differences. These decreases were partially offset by $0.4 million for the change in pretax income, excluding AFUDC equity, $0.2 million to record tax expense at the projected annual effective tax rate, and $0.1 million for miscellaneous tax items.

The effective income tax rate for the six months ended June 30, 2018, and 2017 was 23.9% and 38.1%, respectively. The estimated annual effective income tax rate used during the first six months of 2018 and 2017 for Cleco Power might not be indicative of the full-year income tax rate.

FINANCIAL CONDITION

Liquidity and Capital Resources

General Considerations and Credit-Related Risks

Credit Ratings and Counterparties

Financing for operational needs and capital expenditure requirements not satisfied by operating cash flows depends upon the cost and availability of external funds through both short- and long-term financing. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain or expand its businesses. Access to funds is dependent upon factors such as general economic and capital market conditions, regulatory authorizations and policies, Cleco Holdings’ and Cleco Power’s credit ratings, cash flows from routine operations, and credit ratings of project counterparties. After assessing the current operating performance, liquidity, and credit ratings of Cleco Holdings and Cleco Power, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. The following table presents the credit ratings of Cleco Holdings and Cleco Power at June 30, 2018:

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

On February 7, 2018, taking into consideration the pending NRG South Central acquisition, Moody’s placed Cleco Holdings’ Baa3 long-term issuer credit rating on review for downgrade and affirmed Cleco Power at A3 (stable). Also on February 7, 2018, taking into consideration the pending NRG South Central acquisition, 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. On May 11, 2018, taking into consideration the pending NRG South Central acquisition, Fitch assigned a first-time long-term issuer default rating of BBB- at Cleco Holdings and BBB at

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Cleco Power. On July 31, 2018, Cleco amended its $300.0 million bank term loan agreement and its $100.0 million revolving credit facility agreement to release any and all collateral from all of its debt obligations under those agreements. As a result of the release of collateral, Cleco Holdings expects Moody’s and Fitch to update Cleco Holdings’ senior debt rating.

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

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

With respect to any open power or natural gas trading positions that Cleco Power may initiate in the future, Cleco Power may be required to provide credit support or pay liquidated damages. The amount of credit support that Cleco Power may be required to provide at any point in the future is dependent on the amount of the initial transaction, changes in the market price of power and natural gas, changes in open power and gas positions, and changes in the amount counterparties owe Cleco Power. Changes in any of these factors could cause the amount of requested credit support to increase or decrease.

Cleco Power participates in the MISO market, which operates a fully functioning RTO market with two major market processes: the Day-Ahead Energy and Operating Reserves Market and the Real-Time Energy and Operating Reserves Market. Both use market-based mechanisms to manage transmission congestion across the MISO market area. MISO requires Cleco Power to provide credit support which may increase or decrease due to the timing of the settlement schedules. At June 30, 2018, Cleco Power had a $2.0 million letter of credit to MISO pursuant to the credit requirements of FTRs. The letter of credit automatically renews each year. For information about MISO, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Transmission Rates of Cleco Power” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Global and U.S. Economic Environment

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

payment of such obligations. The lower interest rates to which the Registrants have been exposed have been beneficial to debt issuances; however, these rates have negatively affected interest income for the Registrants’ short-term investments.

2017 Tax Reform

The TCJA was signed into law on December 22, 2017. The provisions of the law reduce the top federal statutory corporate income tax rate from 35% to 21%, generally allow for 100% bonus depreciation for new and used equipment purchased after September 27, 2017, generally restrict deduction of interest expense to 30% of adjusted taxable EBITDA, and repeal the corporate alternative minimum tax. As defined by the TCJA, rate regulated activities are not allowed to utilize 100% bonus depreciation and are not subject to the restricted interest deduction. Cleco Power anticipates filing an application with the LPSC no later than August 31, 2018, for consideration of Cleco Power’s methodology for TCJA refunds and related items, including the allocation of such refunds among Cleco Power’s jurisdictional customers. Rates are anticipated to go into effect October 1, 2018. Cleco Power anticipates refunding the amount accrued for the change in the tax rate for the period January 2018 to September 2018 on customers’ September 2018 bills, based on July 2018 usage, pending LPSC review and approval. Cleco Power expects to address the regulatory liability for excess ADIT resulting from the enactment of the TCJA in Cleco Power’s application for its new FRP, which will be filed by June 30, 2019, with anticipated new rates being effective July 1, 2020. The regulatory treatment for the change in the statutory corporate income tax rate could decrease Cleco Power’s future retail rates, resulting in lower cash flows. As a result of a request by the LPSC, Cleco Power began accruing an estimated reserve for the change in the tax rates beginning January 1, 2018. At June 30, 2018, Cleco Power had $14.7 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.

At December 31, 2017, Cleco reduced net ADIT liability because of the reduction in the income tax rate from 35% to 21%. While activities not subject to cost of service rate regulation record the reduction in ADIT liability in income tax expense, Cleco Power is required to recognize a regulatory liability for the portion of the net reduction subject to regulatory treatment.

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 impacts of the TCJA also resulted in a decrease in the ADIT liability for Cleco and Cleco Power by $394.9 million and $362.9 million, respectively, at December 31, 2017. For the six months ended June 30, 2018, there were no adjustments in the ADIT liability related to the TCJA for Cleco or Cleco Power.

Cleco expects current and deferred income tax expense in future periods to be lower than in past periods. Cleco also expects lower cash taxes to be paid for federal income taxes; however, higher income taxes may be paid for state income taxes because of the lower federal income tax deduction.

The reduction to ADIT discussed above, including the effects on income tax expense, regulatory liabilities, and

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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 that any final adjustments to the provisional amounts will be recorded by the fourth quarter of 2018, which could have a material adverse effect on the results of operations of Cleco. Due to the uncertainty around the regulatory treatment, the entire regulatory liability is reflected in non-current liabilities.

Fair Value Measurements

Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels. Other financial assets and liabilities are reported at their carrying values at their date of issuance on the consolidated balance sheets with their fair values as of the balance sheet date disclosed within the three levels. For more information about fair value levels, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 5 — Fair Value Accounting.”

Cash Generation and Cash Requirements

Restricted Cash and Cash Equivalents

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

Debt

Cleco Consolidated

At June 30, 2018, and December 31, 2017, Cleco had no short-term debt outstanding. Cleco Holdings and Cleco Power have uncommitted lines of credit with a bank that allow up to $10.0 million each in short-term borrowings, but no more than $10.0 million in the aggregate, to support their working capital needs.

At June 30, 2018, Cleco’s long-term debt outstanding was $2.91 billion, of which $20.4 million was due within one year. The long-term debt due within one year at June 30, 2018, represents $19.9 million of principal payments for the Cleco Katrina/Rita storm recovery bonds and $0.5 million of capital lease payments. For Cleco, long-term debt increased by $53.5 million from December 31, 2017, primarily due to the issuance of $50.0 million of senior notes on March 26, 2018, a $16.8 million increase in capital lease obligations, and $0.7 million related to debt discount and expense. These increases were

partially offset by a $9.7 million scheduled payment made on Cleco Katrina/Rita storm recovery bonds, $4.2 million for amortization of long-term debt fair value adjustments related to the Merger, and $0.1 million of capital lease principal payments.

On December 18, 2017, Cleco entered into an agreement for the issuance and sale in a private placement of an aggregate principal amount of $175.0 million of senior notes. For more information, see “— Cleco Power” below.

On April 2, 2018, Cleco entered into a capital lease agreement for use of 42 dedicated barges to transport petroleum coke and limestone to Madison Unit 3. For more information on the capital lease agreement, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — Fuel Transportation Agreement.”

Cash and cash equivalents available at June 30, 2018, were $116.3 million combined with $400.0 million credit facility capacity ($100.0 million from Cleco Holdings and $300.0 million from Cleco Power) for total liquidity of $516.3 million.

At June 30, 2018, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents. In order to mitigate potential credit risk, Cleco and Cleco Power have established guidelines for short-term investments. For more information on the concentration of credit risk through short-term investments classified as cash equivalents, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 5 — Fair Value Accounting.”

At June 30, 2018, and December 31, 2017, Cleco had a working capital surplus of $257.9 million and $271.4 million, respectively. The $13.5 milliondecrease in working capital is primarily due to:

• a $23.5 million increase in taxes payable primarily due to accrual of property taxes and provision for income taxes,

• a $21.1 million increase in provision for rate refund primarily due to the estimated refund due to retail customers for the federal tax-related benefits of the TCJA and the estimated refund for the June 2018 FRP monitoring report,

• an $8.9 million decrease in fuel inventory primarily due to higher usage of lignite, partially offset by higher coal purchases,

• a $6.2 million decrease in other accounts receivable due to the receipt of an insurance reimbursement, timing of pole attachment billings, partially offset by higher receivables from joint owners for maintenance expenses,

• a $3.3 million decrease in other regulatory assets primarily due to amortization of regulatory assets partially offset by a reclass of the retail jurisdictional split for the corporate franchise tax due,

• a $3.1 million decrease in restricted cash and cash equivalents,

• a $2.7 million decrease in cash and cash equivalents,

• a $2.2 million increase in other current liabilities primarily due to higher accruals for SSR capital expenditures, and

• a $1.9 million increase in customer deposits.

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These decreases in working capital were partially offset by:

• a $26.8 increase in accumulated deferred fuel primarily due to the timing of fuel revenue collections and additional deferrals through a fuel surcharge,

• a $16.4 million decrease in accounts payable, excluding FTR purchases, primarily due to a decrease in fuel costs and lower accruals for payroll, and

• a $15.9 million increase in customer accounts receivable and unbilled revenue due to an increase in retail revenue and customer usage.

Cleco Holdings (Holding Company Level)

At June 30, 2018, and December 31, 2017, Cleco Holdings had no short-term debt outstanding. Cleco Holdings and Cleco Power have uncommitted lines of credit with a bank that allow up to $10.0 million each in short-term borrowings, but no more than $10.0 million in the aggregate, to support their working capital needs.

At June 30, 2018, Cleco Holding’s long-term debt outstanding was $1.49 billion, none of which was due within one year.

At June 30, 2018, and December 31, 2017, Cleco Holdings had no borrowings outstanding under its $100.0 million credit facility. This credit facility provides for working capital and other financing needs. The credit facility includes restricted financial covenants and expires in 2021.

Cash and cash equivalents available at June 30, 2018, were $44.7 million, combined with $100.0 million credit facility capacity for total liquidity of $144.7 million.

Cleco Power

At June 30, 2018, and December 31, 2017, Cleco Power had no short-term debt outstanding. Cleco Holdings and Cleco Power have uncommitted lines of credit with a bank that allow up to $10.0 million each in short-term borrowings, but no more than $10.0 million in the aggregate, to support their working capital needs.

At June 30, 2018, Cleco Power’s long-term debt outstanding was $1.42 billion, of which $20.4 million was due within one year. The long-term debt due within one year at June 30, 2018, represents $19.9 million of principal payments for the Cleco Katrina/Rita storm recovery bonds and $0.5 million of capital lease payments. For Cleco Power, long-term debt increased$57.4 million from December 31, 2017, primarily due to the issuance of $50.0 million of senior notes on March 26, 2018, a $16.8 million increase in capital lease obligations, and $0.4 million related to debt discount and expense. These increases were partially offset by a $9.7 million scheduled payment made on Cleco Katrina/Rita storm recovery bonds and $0.1 million of capital lease principal payments.

At June 30, 2018, and December 31, 2017, Cleco Power had no borrowings outstanding under its $300.0 million credit facility. This credit facility provides for working capital and other financing needs. The credit facility includes restricted financial covenants and expires in 2021.

On December 18, 2017, Cleco Power entered into an agreement for the issuance and sale in a private placement of an aggregate principal amount of $175.0 million of senior notes. The senior notes were issued in two tranches. The first tranche was issued on December 18, 2017, with a principal amount 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 a principal amount of $50.0 million at an interest rate of 3.17%, with a final maturity date of December 16, 2024. The proceeds from the issuances and sales were used for capital investments and general utility purposes.

On April 2, 2018, Cleco Power entered into a capital lease agreement for use of 42 dedicated barges to transport petroleum coke and limestone to Madison Unit 3. For more information on the capital lease agreement, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — Fuel Transportation Agreement.”

Cash and cash equivalents available at June 30, 2018, were $71.6 million, combined with $300.0 million credit facility capacity for total liquidity of $371.6 million.

At June 30, 2018, and December 31, 2017, Cleco Power had a working capital surplus of $142.3 million and $169.6 million, respectively. The $27.3 milliondecrease in working capital is primarily due to:

• a $33.0 million increase in taxes payable primarily due to accrual of property taxes and provision for income taxes,

• a $21.1 million increase in provision for rate refund primarily due to the estimated refund due to retail customers for the federal tax-related benefits of the TCJA and the estimated refund for the June 2018 FRP monitoring report,

• an $8.9 million decrease in fuel inventory primarily due to higher usage of lignite, partially offset by higher coal purchases,

• a $6.5 million decrease in other accounts receivable due to the receipt of an insurance reimbursement, timing of pole attachment billings, partially offset by higher receivables from joint owners for maintenance expenses,

• a $3.3 million decrease in other regulatory assets primarily due to amortization of regulatory assets partially offset by a reclass of the retail jurisdictional split for the corporate franchise tax due,

• a $3.1 million decrease in restricted cash and cash equivalents,

• a $2.2 million increase in other current liabilities primarily due to higher accruals for SSR capital expenditures, and

• a $1.9 million increase in customer deposits.

These decreases in working capital were partially offset by:

• a $26.8 increase in accumulated deferred fuel primarily due to the timing of fuel revenue collections and additional deferrals through a fuel surcharge,

• a $15.9 million increase in customer accounts receivable and unbilled revenue due to an increase in retail revenue and customer usage, and

• a $11.1 million decrease in accounts payable, excluding FTR purchases, primarily due to a decrease in fuel costs and lower accruals for payroll.

Credit Facilities

At June 30, 2018, Cleco Holdings had a $100.0 million credit facility. The credit facility includes restricted financial covenants and expires in 2021. At June 30, 2018, Cleco Holdings was in compliance with the covenants of its credit

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facility. The borrowing costs under Cleco Holdings’ credit facility are equal to LIBOR plus 1.75% or ABR plus 0.75%, plus commitment fees of 0.275%. If Cleco Holdings’ credit ratings were to be downgraded one level, Cleco Holdings could be required to pay higher fees and additional interest of 0.075% and 0.50%, respectively, under the pricing levels of its credit facility.

At June 30, 2018, Cleco Power had a $300.0 million credit facility. The credit facility includes restricted financial covenants and expires in 2021. At June 30, 2018, Cleco Power was in compliance with the covenants of its credit facility. The borrowing costs under Cleco Power’s credit facility are equal to LIBOR plus 1.125% or ABR plus 0.125%, plus commitment fees of 0.125%. If Cleco Power’s credit ratings were to be downgraded one level, Cleco Power could be required to pay higher fees and additional interest of 0.05% and 0.125%, respectively, under the pricing levels of its credit facility.

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

Debt Limitations

The Merger Commitments include provisions limiting the amount of distributions that can be made from Cleco Holdings to Cleco Group or Cleco Partners, depending on Cleco Holdings’ debt to EBITDA ratio and its corporate credit ratings. Additionally, in accordance with the Merger Commitments, Cleco Power is subject to certain provisions limiting the amount of distributions that may be paid to Cleco Holdings, depending on Cleco Power’s common equity ratio and its corporate credit ratings. The Merger Commitments also prohibit Cleco from incurring additional long-term debt, excluding non-recourse debt, unless certain financial ratios are achieved. At June 30, 2018, and December 31, 2017, Cleco Holdings and Cleco Power were in compliance with the provisions of the Merger Commitments that could restrict the amount of distributions available. For more information on the Merger Commitments, see Part I, Item 1A, “Risk Factors — Regulatory Compliance” and “— Holding Company” in the Registrants’ Combined Annual Report on Form 10-K for the year ended December 31, 2017.

Cleco Consolidated Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $135.8 million and $87.1 million during the six months ended June 30, 2018, and 2017, respectively. Net cash provided by operating activities increased$48.7 million primarily due to:

• lower payments of $18.0 million due to timing of property tax payments,

• higher receipts from customers of $16.3 million due to timing of collections,

• lower payments for fuel purchases of $13.6 million primarily due to lower deliveries of lignite and petroleum coke,

• higher receipts of $8.8 million primarily due to timing of receipts of joint owners’ portion of generating station expenditures,

• higher receipts of advanced deposits for operations and maintenance costs on jointly owned generating units of $7.0 million,

• higher collections from customers of $4.7 million due to lower Merger credits used in 2018,

• higher collections of $2.4 million primarily due to SSR revenue, and

• lower payments of $2.2 million related to storm restoration efforts.

These increases were partially offset by:

• lower net fuel and power purchase collections of $24.2 million primarily due to timing of collections,

• higher pay out for employee benefits of $8.4 million, and

• higher payments of $6.2 million for NRG South Central acquisition transaction costs.

Net Investing Cash Flow

Net cash used in investing activities was $142.2 million and $125.1 million during the six months ended June 30, 2018, and 2017, respectively. Net cash used in investing activities increased$17.1 million primarily due to:

• issuance of a $16.8 million note receivable and

• higher additions to property, plant, and equipment, net of AFUDC, of $3.8 million.

These increases were partially offset by:

• higher return of investment in the NMTC Fund of $1.9 million and

• higher receipts of insurance reimbursements for property loss of $1.1 million.

For more information about the note receivable, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — Fuel Transportation Agreement.”

Net Financing Cash Flow

Net cash used in financing activities was $0.4 million during the six months ended June 30, 2018. Net cash provided by financing activities was $19.4 million during the six months ended June 30, 2017. Net cash used in financing activities increased$19.8 million primarily due to the absence of draws on Cleco’s credit facilities of $114.0 million.

This increase was partially offset by:

• the $50.0 million issuance of the second tranche of senior notes on March 26, 2018,

• absence of payments on Cleco’s credit facility of $29.0 million, and

• lower distributions to Cleco Group of $15.8 million.

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Cleco Power Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $173.8 million and $94.5 million during the six months ended June 30, 2018, and 2017, respectively. Net cash provided by operating activities increased$79.3 million primarily due to:

• lower payments for affiliate settlements of $26.4 million,

• lower payments of $18.0 million due to timing of property tax payments,

• higher receipts from customers of $16.3 million due to timing of collections,

• lower payments for fuel purchases of $13.6 million primarily due to lower deliveries of lignite and petroleum coke,

• higher receipts of $8.8 million primarily due to timing of receipts of joint owners’ portion of generating station expenditures,

• higher receipts of advanced deposits for operations and maintenance costs on jointly owned generating units of $7.0 million,

• higher collections from customers of $4.7 million due to lower Merger credits used in 2018,

• higher collections of $2.4 million primarily due to SSR revenue, and

• lower payments of $2.2 million related to storm restoration efforts.

These increases were partially offset by:

• lower net fuel and power purchase collections of $24.2 million primarily due to timing of collections and

• higher pay out for employee benefits of $6.2 million.

Net Investing Cash Flow

Net cash used in investing activities was $144.7 million and $123.9 million during the six months ended June 30, 2018, and 2017, respectively. Net cash used in investing activities increased$20.8 million primarily due to:

• issuance of a $16.8 million note receivable and

• higher additions to property, plant, and equipment, net of AFUDC, of $4.8 million.

These increases were partially offset by higher receipts of insurance reimbursements for property loss of $1.1 million.

For more information about the note receivable, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — Fuel Transportation Agreement.”

Net Financing Cash Flow

Net cash provided by financing activities was $31.5 million during the six months ended June 30, 2018. Net cash used in financing activities was $5.3 million during the six months ended June 30, 2017. Net cash used in financing activities increased$36.8 million primarily due to:

• absence of draws on Cleco Power’s credit facility of $90.0 million and

• higher distributions to Cleco Holdings of $11.0 million.

These increases were partially offset by:

• the $50.0 million issuance of the second tranche of senior notes on March 26, 2018, and

• absence of payments on Cleco’s credit facility of $15.0 million.

Contractual Obligations

Cleco, in the normal course of business activities, enters into a variety of contractual obligations. Some of these result in direct obligations that are reflected in Cleco’s Condensed Consolidated Balance Sheets while others are commitments, some firm and some based on uncertainties, that are not reflected in the Condensed Consolidated Financial Statements.

For more information regarding Cleco’s Contractual Obligations, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Contractual Obligations” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Off-Balance Sheet Commitments and Guarantees

Cleco Holdings and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Holdings’ subsidiaries and equity investees (affiliates). Cleco Holdings and Cleco Power have also agreed to contractual terms that require them to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees. For more information about off-balance sheet commitments and on-balance sheet guarantees, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Off-Balance Sheet Commitments and Guarantees.”

Cybersecurity

The operation of Cleco’s electrical systems relies on evolving operational and information technology systems and network infrastructures that are complex. The failure of Cleco’s operational and information technology systems and networks due to a physical or cyberattack, or other event could significantly disrupt operations; cause harm to the public or employees; result in outages or reduced generating output; result in damage to Cleco’s assets or operations, or those of third parties; result in damage to Cleco’s reputation; and subject Cleco to claims by customers or third parties, any of which could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants. In addition, Cleco’s pending acquisition of NRG South Central could increase the risk associated with cybersecurity that could have a material adverse effect on Cleco’s results of operations, financial condition, or cash flows including phishing attacks, denial of service attacks, and employee insider attacks. Cleco continues to assess its cybersecurity tools and processes and has taken a variety of actions to monitor and address cyber-related risks. Cleco’s Chief Information Officer leads Cleco’s cybersecurity team and oversees Cleco’s cybersecurity maturity plan. Each quarter, management provides cybersecurity updates to Cleco’s Board of Managers. For more information on risks related to Cleco’s cybersecurity, see Part I, Item 1A, “Risk Factors — Technology

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and Terrorism Threats” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Regulatory and Other Matters

Environmental Matters

Cleco is subject to extensive environmental regulation by federal, state, and local authorities and is required to comply with numerous environmental laws and regulations, and to obtain and comply with numerous governmental permits, in operating its facilities. In addition, existing environmental laws, regulations, and permits could be revised or reinterpreted; new laws and regulations could be adopted or become applicable to Cleco or its facilities; and future changes in environmental laws and regulations could occur, including potential regulatory and enforcement developments related to air emissions. Cleco may incur significant additional costs to comply with these revisions, reinterpretations, and requirements. Cleco Power would then seek recovery of additional environmental compliance costs as riders through the LPSC’s EAC or FRP. If Cleco fails to comply with these revisions, reinterpretations, and requirements, it could be subject to civil or criminal liabilities and fines.

For a discussion of other Cleco environmental matters, see Part I, Item 1, “Business — Environmental Matters” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Retail Rates of Cleco Power

Fuel Rates

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. For more information on the FAC and the current fuel audit, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Fuel Audit.”

Environmental Rates

In July 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides for an EAC to recover from customers certain costs of environmental compliance. These expenses are eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC. For more information on the EAC and the current environmental audit, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Environmental Audit.”

SSR

Cleco Power is currently operating Teche Unit 3 as an SSR unit as designated by MISO. For more information on the MISO SSR designation of Teche Unit 3, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 10 — Regulation and Rates — SSR.”

Energy Efficiency

In 2013, the LPSC issued a General Order adopting rules promoting energy efficiency programs. The order addressed two energy efficiency programs, Phase I and Phase II. Phase I, known as the Quick Start program, was a three-year program to expedite the energy efficiency implementation and was expected to develop into Phase II, a more detailed and comprehensive program. Cleco Power participated in the Phase I program beginning in November 2014 for three years and designed several energy efficiency programs for customers. In January 2017, the LPSC amended the third year of the Phase I program to allocate no less than 50% of its annual program budgets to applicable government and state agencies. Beginning in November 2014, Cleco Power recovered approximately $3.3 million annually for each of the three program years through an approved rate tariff.

In September 2017, the LPSC extended Phase I for an additional year. Cleco Power began recovery of approximately $3.3 million for estimated costs for the fourth program year beginning January 1, 2018. Also in September 2017, the LPSC approved a motion for additional energy efficiency program funds for the exclusive benefit of school districts, local governments, state agencies, and higher education institutions or any other public entities (political subdivision). The recovery of approximately $3.3 million annually for estimated costs for the political subdivision program began on January 1, 2018.

In November 2017, the LPSC initiated an audit on the first two program years to consider all program costs. Cleco Power responded to the two sets of data requests on the energy efficiency audit. Management is unable to predict or give a reasonable estimate of the outcome of the audit.

MISO Cost Benefit Analysis

Cleco Power entered into MISO in 2013. Within five years of joining MISO, the LPSC required Cleco Power to conduct a study of the costs and benefits of its membership in MISO. During the second quarter of 2017, Cleco Power submitted an analysis with both a backward-looking, historical analysis and a forward-looking, prospective analysis of the costs and benefits of operating in MISO, as compared to a scenario where Cleco Power and Entergy Louisiana exit MISO and operate independently. Cleco Power’s analysis indicated that continued MISO membership would best serve the public interest. Cleco Power has responded to four sets of data requests on the analysis. Management is unable to predict the outcome of this analysis or give a reasonable estimate of the possible range of disallowance of costs, if any.

Wholesale Rates of Cleco Power

The rates Cleco Power charges its wholesale customers are subject to FERC’s triennial market power analysis. FERC requires a utility to pass a screening test as a condition for securing and/or retaining approval to sell electricity in wholesale markets at market-based rates. An updated market power analysis must be filed with FERC every three years or upon the occurrence of a change in status as defined by FERC regulation. Cleco filed its triennial market power analysis with FERC in December 2017. Cleco Power expects a determination from FERC in the third quarter of 2018. Management is unable to predict the outcome of this filing. If FERC determines Cleco Power possesses generation market power in excess of certain thresholds, Cleco Power could lose the right to sell wholesale generation at market-based rates, which could result in a material adverse effect on the results of

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

Transmission Rates of Cleco Power

In May 2017, Cleco Power filed a MISO Schedule 2 rate increase request with FERC. MISO Schedule 2 provides for compensation to Cleco Power for providing reactive power to MISO customers. On July 1, 2017, Cleco Power began collecting revenue at the requested rate, subject to refund. On December 1, 2017, a new rate in pursuance with interveners, became effective. FERC approved this rate on February 1, 2018. In April 2018, Cleco refunded $0.1 million, including accrued interest, for the amount over-collected in 2017.

Two complaints were filed with FERC seeking to reduce the ROE component of the transmission rates that MISO transmission owners, including Cleco, may collect under the MISO tariff. For more information about the ROE complaints, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — Transmission ROE.”

For information about the risks associated with Cleco Power’s participation in MISO, see Part I, Item 1A, “Risk Factors — MISO” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

For information on transmission rates of Cleco Power, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Transmission Rates of Cleco Power” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Transmission and Generation Projects

Cleco Power is currently involved in the Terrebonne to Bayou Vista Transmission project. Cleco Power is also involved in the St. Mary Clean Energy Center project, which is a waste heat generating unit, and the Coughlin Pipeline project. For information on these projects, see “— Overview — Cleco Power.”

Market Restructuring

Wholesale Electric Markets

RTO

For information on Cleco Power’s operations within MISO and for information on regulatory aspects of wholesale electric markets affecting Cleco, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Market Restructuring — Wholesale Electric Markets” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

ERO

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

In July 2017, the SPP RTO’s board of directors and members committee voted to authorize the SPP’s President and CEO to terminate the delegation agreement between the

SPP and NERC. On February 8, 2018, NERC approved Cleco Power’s proposed RE. On July 1, 2018, SERC Reliability Corporation (SERC) assumed the delegated authority as the new RE for Cleco Power, which replaced the SPP RE. Management does not expect the movement to SERC will have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

A NERC Reliability Standards audit is conducted every three years. Cleco Power’s next NERC Reliability Standards audit is scheduled to begin in 2019.

A NERC Critical Infrastructure Protection audit is also conducted every three years. A NERC Critical Infrastructure Protection audit was conducted in February 2017. There were three violations associated with the February 2017 audit. Cleco Power has completed the mitigation plans for the violations. The SPP RE has approved two of the mitigation plans. The third mitigation plan has been transferred to SERC due to the dissolution of the SPP RE. Cleco Power’s next NERC Critical Infrastructure Protection audit is scheduled to begin in 2020. Management is unable to predict the final outcome of the remaining violation, or any future audits, or whether any findings will have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.

For a discussion of risks associated with FERC’s regulation of Cleco Power’s transmission system, see Part I, Item 1A, “Risk Factors — Reliability and Infrastructure Protection Standards Compliance” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Retail Electric Markets

For information on the regulatory aspects of retail electric markets affecting Cleco Power, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Market Restructuring — Retail Electric Markets” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Lignite Deferral

At June 30, 2018, and December 31, 2017, Cleco Power had $2.5 million and $3.8 million, respectively, in uncollected deferred lignite mining costs.

For more information on Cleco Power’s deferred lignite mining expenditures, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Lignite Deferral” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Integrated Resource Plan (IRP)

In accordance with the General Order in LPSC Docket No. R-30021, on October 20, 2017, Cleco Power filed a request with the LPSC to initiate an IRP process. On February 20, 2018, Cleco Power filed the data assumptions to be used in its IRP analysis. The IRP process includes conducting stakeholder meetings and receiving feedback from stakeholders. The first stakeholder meeting was held on April 5, 2018. Comments from the stakeholders were filed on June 5, 2018. Cleco Power responded to multiple sets of data requests. The schedule outlined in the General Order calls for

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Cleco Power to file a draft IRP in January 2019, and a final report in August 2019.

Franchises

Cleco Power operates under nonexclusive franchise rights granted by governmental units, such as municipalities and parishes (counties), and enforced by state law. Cleco Power’snext municipal franchise expires in July 2021.

For more information on franchises, see Part I, Item 1, “Business Regulatory Matters, Industry Developments, and Franchises — Franchises” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

Recent Authoritative Guidance

For a discussion of recent authoritative guidance, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 3 — Recent Authoritative Guidance.”

CRITICAL ACCOUNTING POLICIES

Cleco’s critical accounting policies include accounting policies that are important to Cleco’s financial condition and results of operations and that require management to make difficult, subjective, or complex judgments about future events, which could result in a material impact to the financial statements of Cleco. The preparation of financial statements contained in this report requires management to make estimates and assumptions. Estimates and assumptions about future events and their effects cannot be made with certainty. These

estimates involve judgments regarding many factors that in and of themselves could materially affect the financial statements and disclosures. On an ongoing basis, these estimates and assumptions are evaluated and, if necessary, adjustments are made when warranted by new or updated information or by a change in circumstances or environment. Actual results may differ significantly from these estimates under different assumptions or conditions.

For more information on Cleco’s critical accounting policies, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Critical Accounting Policies” in the Registrant’s Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017.

CLECO POWER — NARRATIVE ANALYSIS OF RESULTS OF OPERATIONS

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

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Risk Overview

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 evaluates derivatives and hedging activities to determine whether market risk-sensitive instruments and positions are required to be marked-to-market. When positions close, actual gains or losses are included in the FAC and reflected on customers’ bills as a component of the FAC.

Cleco’s exposure to market risk, as discussed below, represents an estimate of possible changes in the fair value or future earnings that would occur, assuming possible future movements in the interest rates and commodity prices of power, FTRs, and natural gas. Management’s views on market risk are not necessarily indicative of actual results, nor do they represent the maximum possible gains or losses. The views do represent, within the parameters disclosed, what management estimates may happen.

Cleco maintains a master netting agreement policy and monitors credit risk exposure through reviews 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.

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. Future actions or inactions of the federal government, including a failure to increase the government debt limit, could increase the actual or perceived risk that the U.S. may not pay its obligations when due and may disrupt financial markets, including capital markets, potentially limiting availability and increasing costs of capital. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain and expand its businesses. After assessing the current operating performance, liquidity, and credit ratings of Cleco Holdings and Cleco Power, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. Cleco Holdings and Cleco Power pay fees and interest under their respective credit facilities based on the highest rating held. On February 7, 2018, taking into consideration the pending NRG South Central acquisition, Moody’s placed Cleco Holdings’ Baa3 long-term issuer credit rating on review for downgrade and affirmed Cleco Power at A3 (stable). Also on February 7, 2018, taking into consideration the pending NRG South Central acquisition, 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. On May 11, 2018, taking into consideration the pending NRG South Central acquisition, Fitch assigned a first-time long-term issuer default rating of BBB- at Cleco Holdings and BBB at Cleco Power. If Cleco

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Holdings’ or Cleco Power’s credit ratings were to be downgraded Cleco Holdings or Cleco Power could be required to pay additional fees and incur higher interest rates for borrowings under their respective credit facilities. On July 31, 2018, Cleco amended its $300.0 million bank term loan agreement and its $100.0 million revolving credit facility agreement to release any and all collateral from all of its debt obligations under those agreements. As a result of the release of collateral, Cleco Holdings expects Moody’s and Fitch to update Cleco Holdings’ senior debt rating.

Interest Rate Risks

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

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

At June 30, 2018, Cleco Holdings had no variable-rate debt outstanding under its $100.0 million credit facility. The borrowing costs under Cleco Holdings’ credit facility are equal to LIBOR plus 1.75% or ABR plus 0.75%, plus commitment fees of 0.275%.

At June 30, 2018, Cleco Holdings had a $300.0 million long-term variable rate bank term loan outstanding. Amounts outstanding under the bank term loan bear interest at LIBOR plus 1.625%. At June 30, 2018, the all-in rate was 3.72%. Each 1% increase in the interest rate applicable to such debt would result in a decrease in Cleco Holdings’ pretax earnings of $3.0 million.

For information on variable-rate debt related to Cleco Power, please refer to “— Cleco Power.”

Commodity Price Risks

Management believes Cleco has controls in place to minimize the risks involved in its financial and energy commodity activities. Independent controls over energy commodity functions consist of a middle office (risk management), a back office (accounting), and regulatory compliance staff. All forward commodity positions have established risk limits and are monitored through a daily market report that identifies the VaR, current market conditions, and concentration of energy market positions.

Cleco Power provides fuel for generation and purchases power to meet the power demands of customers. Cleco Power may enter into positions to mitigate the volatility in customer fuel costs, as encouraged by various LPSC orders. These positions would be marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of the

accumulated deferred fuel asset or liability and a component of the energy risk management assets or liabilities. When these positions close, actual gains or losses would be included in the FAC and reflected in customers’ bills as a component of the fuel charge. There were no open natural gas positions at June 30, 2018. Cleco Power is currently working with the LPSC to establish a natural gas hedging pilot program. For more information on the program, see Item 1, “Notes to Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — 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. At June 30, 2018, Cleco Power’s Condensed Consolidated Balance Sheets reflected open FTR positions of $26.1 million in Energy risk management assets and $0.9 million in Other current liabilities. For more information on FTRs, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 5 — Fair Value Accounting — Commodity Contracts.”

Cleco Power

Please refer to “— Risk Overview” for a discussion of market risk inherent in Cleco Power’s market risk-sensitive instruments.

Cleco Power may enter into various fixed- and variable-rate debt obligations. Please refer to “— Interest Rate Risks” for a discussion of how Cleco Power monitors its mix of fixed- and variable-rate debt obligations and the manner of calculating changes in fair market value and interest expense of its debt obligations.

At June 30, 2018, Cleco Power had no variable-rate debt outstanding and no debt outstanding under its $300.0 million credit facility. The borrowing costs under the Cleco Power credit facility are equal to LIBOR plus 1.125% or ABR plus 0.125%, plus commitment fees of 0.125%.

Please refer to “— Commodity Price Risks” for a discussion of controls, transactions, VaR, and market value maturities associated with Cleco Power’s energy commodity activities.

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ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

Under the supervision and with the participation of Cleco Holdings and Cleco Power (individually, “Registrant” and collectively, the “Registrants”) management, including the CEO and CFO, the Registrants have evaluated the effectiveness of their disclosure controls and procedures as of June 30, 2018. Based on the evaluations, the CEO and CFO have concluded that the Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in SEC rules and forms; and that the Registrants’ disclosure

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

Changes in Internal Control over Financial Reporting

There have been no changes in the Registrants’ internal control over financial reporting that occurred during the quarter ended June 30, 2018, that have materially affected, or are reasonably likely to materially affect, the Registrants’ internal control over financial reporting.

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PART II — OTHER INFORMATION

ITEM 1.  LEGAL PROCEEDINGS

CLECO

For information on legal proceedings affecting Cleco, see Part I, Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation.”

CLECO POWER

For information on legal proceedings affecting Cleco Power, see Part I, Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation.”

ITEM 1A. RISK FACTORS

Other than the addition of the FERC Audit risk factor below, there have been no material changes from the risk factors disclosed in Part I, Item 1A, “Risk Factors” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2017 (the “2017 Annual Report on Form 10-K”). For risks that could affect actual results and cause results to differ materially from those expressed in any forward-looking statements made by, or on behalf of, the Registrants, see the risk factors disclosed under Part I, Item 1A, “Risk Factors” of the 2017 Annual Report on Form 10-K.

FERC Audit

FERC conducts audits that could result in Cleco Power making refunds of previously recorded revenue.

Generally, Cleco Power records wholesale transmission revenue through Attachment O of the MISO tariff and certain

grandfathered agreements. These formulas are based on inputs from Cleco Power’s annual FERC Form 1. These rates and regulatory filings are subject to periodic audits by FERC. 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 of January 1, 2014, to the present. Management is unable to predict or give a reasonable estimate of the possible range of the refund, if any, related to this audit. Any such refund could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.

ITEM 4.MINE SAFETY DISCLOSURES

The information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010

and Item 104 of Regulation S-K is included in Exhibit 95 to this Combined Quarterly Report on Form 10-Q.

61

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

ITEM 5. OTHER INFORMATION

As previously disclosed by Cleco Holdings in its Current Report on Form 8-K filed with the SEC on July 1, 2016 (the “July 2016 Form 8-K”), on June 28, 2016, Cleco Holdings entered into a Term Loan Credit Agreement with Mizuho Bank, Ltd., as administrative agent, the lenders party thereto, Mizuho Bank, Ltd., Canadian Imperial Bank of Commerce, New York Branch, JPMorgan Chase Bank, N.A., Regions Bank, Sumitomo Mitsui Banking Corporation, The Bank of Nova Scotia and Wells Fargo Bank, N.A., as joint lead arrangers and joint bookrunners, under which Cleco Holdings’ obligations are secured by a pledge of Cleco Holdings’ equity interests in its wholly-owned subsidiary, Cleco Power. On July 31, 2018, Cleco Holdings entered into a Consent to Release of Collateral (Term Loan Credit Agreement) (“Term Loan Consent”) with the Lenders party thereto (the “Lenders”), and Mizuho Bank, Ltd., as administrative agent (in such capacity, the “Administrative Agent”) pursuant to which the Lenders and the Administrative Agent consented to release the pledge of the Cleco Power equity interests securing Cleco Holdings’ obligations under the Term Loan Agreement.

As previously disclosed in its Current Report on Form 8-K filed with the SEC on April 19, 2016 (the “April 2016 Form 8-K”), Cleco Holdings became a party to that certain Credit Agreement, dated as of April 13, 2016, by and among Cleco Holdings,  Mizuho Bank, Ltd., as administrative agent, Canadian Imperial Bank of Commerce, New York branch, Credit Agricole Corporate and Investment Bank, Mizuho Bank, Ltd., Sumitomo Mitsui Banking Corporation and The Bank of Nova Scotia, as joint lead arrangers and joint bookrunners, and the other lenders named therein (the “Acquisition Loan Agreement”), under which, Cleco Holdings’ obligations are secured by a pledge of Cleco Holdings’ equity interests in Cleco Power. On July 31, 2018, Cleco Holdings entered into a Consent to Release of Collateral (Holdco Acquisition Credit

Agreement) (“Acquisition Loan Consent”) with the Lenders party thereto (the “Acquisition Loan Lenders”), and Mizuho Bank, Ltd., as administrative agent (in such capacity, the “Acquisition Loan Administrative Agent”), as Issuing Bank and as Swingline Lender, pursuant to which the Acquisition Loan Lenders and the Acquisition Loan Administrative Agent consented to release the pledge of the Cleco Power equity interests securing Cleco Holdings’ obligations under the Acquisition Loan Agreement.

As consideration for the Term Loan Consent and the Acquisition Loan Consent and the release of collateral contemplated thereby, Cleco Holdings will pay an aggregate amount of $0.6 million to the Term Loan Lenders and Acquisition Loan Lenders.

Except as specifically provided in the Term Loan Consent and the Acquisition Loan Consent, all of the terms and provisions of the Term Loan Credit Agreement and the Acquisition Loan Agreement, respectively, remain in full force and effect.

The foregoing descriptions of the Term Loan Consent and the Acquisition Loan Consent do not purport to be complete and are qualified in their entirety to the full text of the Term Loan Consent and the Acquisition Loan Consent, respectively, copies of which are filed herewith as Exhibit 10.1 and 10.2, respectively, and are incorporated herein by reference. The forgoing descriptions of the Term Loan Agreement and the Acquisition Loan Agreement do not purport to be complete and are qualified in their entirety to the full text of the Term Loan Agreement and the Acquisition Loan Agreement, respectively, copies of which are filed as Exhibit 10.1 to the July 2016 Form 8-K and Exhibit 10.1 to the April 2016 Form 8-K, respectively, and are incorporated herein by reference.

62

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

ITEM 6.   EXHIBITS
CLECO
10.1	Consent to Release of Collateral (Term Loan Credit Agreement), dated as of July 31, 2018, by and among Cleco Corporate Holdings LLC, the Lenders party thereto, and Mizuho Bank, Ltd., as administrative agent.
10.2	Consent to Release of Collateral (Holdco Acquisition Credit Agreement), dated as of July 31, 2018, by and among Cleco Corporate Holdings LLC, the Lenders party thereto, and Mizuho Bank, Ltd., as administrative agent, as Issuing Bank and as Swingline Lender.
10.3	Credit Agreement, dated as of April 13, 2016, by and among Cleco Corporate Holdings LLC (f/k/a Cleco Corporation), Mizuho Bank, Ltd., as administrative agent, and the lenders from time to time party thereto (incorporated by reference to Exhibit 10.1 of the Current Report on Form 8-K of Cleco Corporate Holdings LLC filed on April 19, 2016).
10.4	Term Loan Credit Agreement, dated as of June 28, 2016, by and among Cleco Corporate Holdings LLC (f/k/a Cleco Corporation), Mizuho Bank, Ltd., as Administrative Agent, and the lenders from time to time party thereto (incorporated by reference to Exhibit 10.1 of the Current Report on Form 8-K of Cleco Corporate Holdings LLC filed on July 1, 2016).
12(a)	Computation of Ratios of Earnings to Fixed Charges
31.1	CEO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
31.2	CFO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
32.1	CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
32.2	CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
95	Mine Safety Disclosures
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase
CLECO POWER
12(b)	Computation of Ratios of Earnings to Fixed Charges
31.3	CEO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
31.4	CFO Certification pursuant to section 302 of the Sarbanes-Oxley Act of 2002
32.3	CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
32.4	CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
95	Mine Safety Disclosures
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase

63

CLECO
CLECO POWER	2018 2ND QUARTER FORM 10-Q

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

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

Date: August 1, 2018

Pursuant to the requirements of the Securities Exchange Act of 1934, the Registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

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

Date: August 1, 2018

64

EX-10.1

Exhibit 10.1

EXECUTION VERSION

AMENDMENT AND CONSENT TO RELEASE OF COLLATERAL (TERM LOAN

CREDIT AGREEMENT)

This AMENDMENT AND CONSENT TO RELEASE OF COLLATERAL (this “Consent”) is made as of July 30, 2018, by and amongCLECO CORPORATE HOLDINGS LLC (f/k/a CLECO CORPORATION), a Louisiana limited liability company (the “Borrower”), the LENDERS party hereto (the “Lenders”), and MIZUHO BANK, LTD., as administrative agent (in such capacity, the “Administrative Agent”).

RECITALS

WHEREAS, the Borrower, the Lenders and the Administrative Agent are parties to that certain Term Loan Credit Agreement, dated as of June 28, 2016 (as amended, restated, supplemented or otherwise modified from time to time, the “Term Loan Credit Agreement”);

WHEREAS, the Borrower, the Administrative Agent, Mizuho Bank, Ltd., in its capacity as Intercreditor Agent (the “Intercreditor Agent”), Wells Fargo Bank, N.A., in its capacity as Collateral Agent (the “Collateral Agent”), and each other secured party from time to time party thereto, are parties to that certain Collateral Agency and Intercreditor Agreement, dated as of April 13, 2016 (as amended, restated, supplemented or otherwise modified from time to time, the “Pari Passu Intercreditor Agreement”);

WHEREAS, the Borrower has requested that the Lenders and the Administrative Agent release the Liens encumbering the Collateral (as defined in the Pledge Agreement, and hereinafter referred to as the “Released Collateral”) pursuant to the Pledge Agreement, dated as of April 13, 2016, by the Borrower in favor of the Collateral Agent (as amended, restated, supplemented or otherwise modified from time to time, the “Pledge Agreement”), as security for the Lenders and the Administrative Agent in their capacity as Secured Parties under, and as defined in, the Pari Passu Intercreditor Agreement; and

WHEREAS, the Lenders and the Administrative Agent desire to release such Liens over the Released Collateral on the terms and conditions set forth in this Consent.

NOW, THEREFORE, in consideration of the mutual covenants and agreements herein contained, the parties hereto agree as follows:

Article I.

DEFINITIONS

Section 1.1    Capitalized terms used and not otherwise specifically defined in this Consent shall have the meanings given to such terms in the Term Loan Credit Agreement.

Section 1.2    The rules of construction set forth in Section 1.03 of the Term Loan Credit Agreement shall apply to this Consent and are hereby incorporated by reference, mutatis mutandis, with the same force and effect as if fully set forth in this Consent.

1 Cleco - Consent to Term Loan Credit Agreement

Article II.

AMENDMENT AND CONSENT TO RELEASE OF COLLATERAL COLLATERAL

Section 2.1    On the Effective Date (as defined below), each of the Lenders and the Administrative Agent hereby agrees that (a) the Liens granted in favor of the Collateral Agent for the benefit of the Lenders and the Administrative Agent as Secured Parties (as defined in the Pari Passu Intercreditor Agreement) under the Pledge Agreement shall be automatically, absolutely, unconditionally, irrevocably and forever discharged, terminated and released, such discharge, termination and release to be without prejudice whatsoever to the Liens granted in favor of the Collateral Agent under the Pledge Agreement for the benefit of Secured Parties (as defined in the Pari Passu Intercreditor Agreement) other than the Lenders and the Administrative Agent, and (b) the Lenders and Administrative Agent shall cease to be Secured Parties (as defined in the Pari Passu Intercreditor Agreement) under the Pledge Agreement.

Section 2.2    At any time and from time to time from and after the Effective Date (as defined below), upon the written request and solely at the expense of the Borrower, the Lenders hereby instruct the Administrative Agent to execute and deliver (or to instruct the Collateral Agent or the Intercreditor Agent, as applicable, to execute and deliver) all such releases, discharges, termination statements, notices, certificates, instruments and documents and take such further action as the Borrower may reasonably request to effectuate, evidence or reflect of public record, the release of the security interests and Liens of the Lenders and the Administrative Agent relating to the Released Collateral as specifically referred to in this Consent.

Section 2.3    As of the Effective Date, subject to the terms and conditions set forth herein, the Lenders, the Administrative Agent and the Borrower hereby agree to amend the Term Loan Credit Agreement as follows:

(a)the definition of “Applicable Margin” in Section 1.01 of the Term Loan Credit Agreement is amended by deleting the word “secured” where it appears in clauses (f) and (g) of such definition and replacing it with the word “unsecured”;

(b)the definition of “Applicable Rating” in Section 1.01 of the Term Loan Credit Agreement is amended by deleting the word “secured” where it appears in such definition and replacing it with the word “unsecured”;

(c)the definition of “Senior Debt Rating” in Section 1.01 of the Term Loan Credit Agreement is amended by deleting the word “secured” where it appears in such definition and replacing it with the word “unsecured”; and

(d)Section 5.13 of the Term Loan Credit Agreement is amended by deleting the word “secured” where it appears in such provision and replacing it with the word “unsecured”.

Section 2.4    As consideration for this Consent and the release of the security interests and Liens of the Lenders and the Administrative Agent relating to the Released

2 Cleco - Consent to Term Loan Credit Agreement

Collateral as set forth herein, the Borrower will pay a fee to each Lender in an amount equal to fifteen (15) basis points of such Lender’s Commitment as of the Effective Date under the Term Loan Credit Agreement (collectively, the “Consent Fee”).

Article III.

CONDITIONS TO EFFECTIVENESS

Section 3.1    This Consent shall become effective on and as of the date (the “Effective Date”) on which each of the following conditions precedent shall have been satisfied in full:

(a)the Administrative Agent shall have received counterparts of this Consent executed by the Borrower, all Lenders and the Administrative Agent;

(b)the Borrower shall have paid the Consent Fee; and

(c)the Administrative Agent and the Borrower shall have received a copy of the certificate of the Borrower dated the Effective Date (the “Indenture Collateral Release Certificate”), duly signed by the Borrower and the Intercreditor Agent (as defined in the Pari Passu Intercreditor Agreement), required to be delivered by the Borrower to Wells Fargo Bank, N.A., as trustee (in such capacity, the “Trustee”), pursuant to Section 12.03(a) of that certain Indenture, dated as of May 17, 2016 (as amended, restated, supplemented or otherwise modified from time to time, the “Indenture”), to confirm that the conditions set forth in Section 12.03(a) of the Indenture have been satisfied.

Article IV.

COVENANT

Section 4.1    The Borrower shall promptly, but no later than three Business Days, after the Effective Date provide evidence reasonably satisfactory to the Administrative Agent that the Borrower has delivered to the Trustee the Indenture Collateral Release Certificate. The Borrower agrees and confirms that failure to deliver the Indenture Collateral Release Certificate to the Trustee in accordance with the preceding sentence shall constitute an immediate Event of Default under the Term Loan Credit Agreement.

Article V.

REPRESENTATIONS AND WARRANTIES

Section 5.1In order to induce each of the Lenders and the Administrative Agent to provide this Consent, the Borrower represents and warrants as of the date hereof and as of the Effective Date, which representations and warranties shall survive the execution of this Consent and the Effective Date, that:

(a)all necessary action on the part of the Borrower required to authorize the execution, delivery and performance of this Consent has been duly and effectively taken;

3 Cleco - Consent to Term Loan Credit Agreement

(b)the execution, delivery and performance of this Consent has been duly authorized by all necessary action on the part of the Borrower, and this Consent has been executed and delivered by the Borrower and constitutes the legal, valid and binding obligations of the Borrower, enforceable against the Borrower in accordance with the terms thereof, except as may be limited by applicable bankruptcy, insolvency, reorganization, moratorium, fraudulent conveyance or similar laws affecting the rights of creditors generally and subject to general principles of equity (regardless of whether considered in equity or at law);

(c)none of the execution, delivery or performance by the Borrower of this Consent (i) violates, contravenes or conflicts with the terms of the Borrower’s Constitutive Documents or (ii) violates or constitutes a default or requires consent (except for such consents that have been obtained or are not required at the date this representation is made or repeated) by the Borrower under any material Governmental Rule applicable to the Borrower or any other material contractual obligation to which the Borrower or any such Subsidiary is a party, except for, with respect solely to clause (ii) hereof, for any defaults or violations or consents that would not reasonably be expected to result in a Material Adverse Effect;

(d)after giving effect to this Consent, no Indebtedness of the Borrower will be secured by the Released Collateral, other than the Indebtedness issued pursuant to the Indenture; and

(e)no Default or Event of Default has occurred and is continuing.

Article VI.

GENERAL PROVISIONS

Section 6.1Reference to the Effect on the Financing Documents.

(a)On and after the Effective Date, each reference in the Term Loan Credit Agreement to “this Agreement”, “hereunder”, “hereof” or words of like import referring to the Term Loan Credit Agreement, and each reference in each other Financing Document to “the Term Loan Credit Agreement”, “Credit Agreement”, “thereunder”, “thereof” or words of like import referring to the Term Loan Credit Agreement, shall mean and be a reference to the Term Loan Credit Agreement, as amended by this Consent.

(b)Except as specifically provided above, all of the terms and provisions of the Term Loan Credit Agreement and all other Financing Documents are and shall remain in full force and effect and are hereby ratified and confirmed.

(c)The execution, delivery and effectiveness of this Consent shall not, except as expressly provided herein, operate as a waiver or amendment of any right, power or remedy of the Lenders or the Administrative Agent under any of the Financing

4 Cleco - Consent to Term Loan Credit Agreement

Documents, nor constitute a waiver or amendment of any other provision of any of the Financing Documents or for any purpose except as expressly set forth herein.

(d)This Consent is a Financing Document.

Section 6.2No Oral Modification. This Consent may not be amended, supplemented, modified or waived, except in accordance with the Financing Documents.

Section 6.3Binding Upon Successors and Assigns. This Consent shall inure to the benefit of, and shall be binding upon, the parties hereto and their respective successors and permitted assigns under the Financing Documents.

Section 6.4Execution in Counterparts. This Consent may be executed in several counterparts, each of which is an original (and by different parties hereto in different counterparts), but all of which together constitute one and the same agreement. This Consent and the other Financing Documents constitute the entire contract among the parties relating to the subject matter hereof and supersedes any and all previous agreement and understanding, oral or written, relating to the subject matter hereof. Delivery of an executed counterpart of a signature page of this Consent by facsimile or other electronic imaging means (e.g. “pdf” or “tif”) shall be effective as delivery of a manually executed counterpart of this Consent.

Section 6.5Notices; Applicable Law and Jurisdiction. The provisions set forth in Sections 9.01 (Notices), 9.02 (Waivers; Amendments), 9.03 (Expenses; Indemnity; Damage Waiver), 9.05 (Survival), 9.07 (Severability), 9.09 (Governing Law; Jurisdiction; Consent to Service of Process), 9.10 (WAIVER OF JURY TRIAL), 9.11 (Headings) and 9.12 (Confidentiality) of the Term Loan Credit Agreement shall apply to this Consent and are hereby incorporated by reference, mutatis mutandis, with the same force and effect as if fully set forth in this Consent (and as if each reference to “this Agreement” were a reference to this Consent).

Section 6.6Instruction to Administrative Agent. The Lenders hereby instruct the Administrative Agent to direct the Intercreditor Agent and the Collateral Agent under the Pari Passu Intercreditor Agreement to execute and deliver Amendment No. 1 to the Pari Passu Intercreditor Agreement in substantially the form attached hereto as Exhibit A.

[Signature Pages Follow]

5 Cleco - Consent to Term Loan Credit Agreement

IN WITNESS WHEREOF, this Consent has been executed by the undersigned as of the date first set forth above.

CLECO CORPORATE HOLDINGS LLC, as Borrower
By	/s/ Terry L. Taylor
Name:	Terry L. Taylor
Title:	Chief Financial Officer
By	/s/ Julia E. Callis
Name:	Julia E. Callis
Title:	Chief Compliance Officer & General Counsel

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

CANADIAN IMPERIAL BANK OF COMMERCE, NEW YORK BRANCH, as a Lender
By:	/s/ Anju Abraham
Name:	Anju Abraham
Title:	Authorized Signatory
By:	/s/ Gordon R. Eadon
Name:	Gordon R. Eadon
Title:	Authorized Signatory

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

JPMORGAN CHASE BANK, N.A., as a Lender
By:	/s/ Helen D. Davis
Name:	Helen D. Davis
Title:	Executive Director

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

MIZUHO BANK, LTD., as a Lender
By:	/s/ Tracy Rahn
Name:	Tracy Rahn
Title:	Authorized Signatory

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

REGIONS BANK, as a Lender
By:	/s/ Brian Walsh
Name:	Brian Walsh
Title:	Director

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

SUMITOMO MITSUI BANKING CORPORATION, as a Lender
By:	/s/ James D. Weinstein
Name:	James D. Weinstein
Title:	Managing Director

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

THE BANK OF NOVA SCOTIA, as a Lender
By:	/s/ David Dewar
Name:	David Dewar
Title:	Director

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

WELLS FARGO BANK, N.A., as a Lender
By:	/s/ Jesse Tannuzzo
Name:	Jesse Tannuzzo
Title:	Vice President

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

MIZUHO BANK, LTD., as Administrative Agent
By:	/s/ Tracy Rahn
Name:	Tracy Rahn
Title:	Authorized Signatory

Signature Page to Consent to the Release of Collateral (Term Loan Credit Agreement)

Exhibit A

Amendment No. 1 to Pari Passu Intercreditor Agreement

[Attached]

Exhibit A to Consent to the Release of Collateral (Term Loan Credit Agreement)

EX-10.2

Exhibit 10.2

EXECUTION VERSION

AMENDMENT AND CONSENT TO RELEASE OF COLLATERAL (HOLDCO

ACQUISITION CREDIT AGREEMENT)

This AMENDMENT AND CONSENT TO RELEASE OF COLLATERAL (this “Consent”) is made as of July 30, 2018, by and amongCLECO CORPORATE HOLDINGS LLC (f/k/a CLECO CORPORATION), a Louisiana limited liability company (the “Borrower”), the LENDERS party hereto (the “Lenders”), and MIZUHO BANK, LTD., as administrative agent (in such capacity, the “Administrative Agent”), as Issuing Bank (in such capacity, the “Issuing Bank”) and as Swingline Lender (in such capacity, the “Swingline Lender”).

RECITALS

WHEREAS, the Borrower, the Lenders and the Administrative Agent are parties to that certain Credit Agreement, dated as of April 13, 2016 (as amended, restated, supplemented or otherwise modified from time to time, the “HoldCo Acquisition Credit Agreement”);

WHEREAS, the Borrower, the Administrative Agent, Mizuho Bank, Ltd., in its capacity as Intercreditor Agent (the “Intercreditor Agent”), Wells Fargo Bank, N.A., in its capacity as Collateral Agent (the “Collateral Agent”), and each other secured party from time to time party thereto, are parties to that certain Collateral Agency and Intercreditor Agreement, dated as of April 13, 2016 (as amended, restated, supplemented or otherwise modified from time to time, the “Pari Passu Intercreditor Agreement”);

WHEREAS, the Borrower has requested that the Lenders and the Administrative Agent release the Liens encumbering the Collateral (as defined in the Pledge Agreement, and hereinafter referred to as the “Released Collateral”) pursuant to the Pledge Agreement, dated as of April 13, 2016, by the Borrower in favor of the Collateral Agent (as amended, restated, supplemented or otherwise modified from time to time, the “Pledge Agreement”), as security for the Lenders and the Administrative Agent in their capacity as Secured Parties under, and as defined in, the Pari Passu Intercreditor Agreement; and

WHEREAS, the Lenders and the Administrative Agent desire to release such Liens over the Released Collateral on the terms and conditions set forth in this Consent.

NOW, THEREFORE, in consideration of the mutual covenants and agreements herein contained, the parties hereto agree as follows:

Article I.

DEFINITIONS

Section 1.1Capitalized terms used and not otherwise specifically defined in this Consent shall have the meanings given to such terms in the HoldCo Acquisition Credit Agreement.

1 Cleco - Consent to HoldCo Acquisition Credit Agreement

Section 1.2The rules of construction set forth in Section 1.03 of the HoldCo Acquisition Credit Agreement shall apply to this Consent and are hereby incorporated by reference, mutatis mutandis, with the same force and effect as if fully set forth in this Consent.

Article II.

AMENDMENT AND consent to release of COLLATERAL

Section 2.1On the Effective Date (as defined below), each of the Lenders and the Administrative Agent hereby agrees that (a) the Liens granted in favor of the Collateral Agent for the benefit of the Lenders and the Administrative Agent as Secured Parties (as defined in the Pari Passu Intercreditor Agreement) under the Pledge Agreement shall be automatically, absolutely, unconditionally, irrevocably and forever discharged, terminated and released, such discharge, termination and release to be without prejudice whatsoever to the Liens granted in favor of the Collateral Agent under the Pledge Agreement for the benefit of Secured Parties (as defined in the Pari Passu Intercreditor Agreement) other than the Lenders and the Administrative Agent, and (b) the Lenders and Administrative Agent shall cease to be Secured Parties (as defined in the Pari Passu Intercreditor Agreement) under the Pledge Agreement.

Section 2.2At any time and from time to time from and after the Effective Date (as defined below), upon the written request and solely at the expense of the Borrower, the Lenders hereby instruct the Administrative Agent to execute and deliver (or to instruct the Collateral Agent or the Intercreditor Agent, as applicable, to execute and deliver) all such releases, discharges, termination statements, notices, certificates, instruments and documents and take such further action as the Borrower may reasonably request to effectuate, evidence or reflect of public record, the release of the security interests and Liens of the Lenders and the Administrative Agent relating to the Released Collateral as specifically referred to in this Consent.

Section 2.3As of the Effective Date, subject to the terms and conditions set forth herein, the Lenders, the Administrative Agent and the Borrower hereby agree to amend the HoldCo Acquisition Credit Agreement as follows:

(a)the definition of “Applicable Rating” in Section 1.01 of the HoldCo Acquisition Credit Agreement is amended by deleting the word “secured” where it appears in such definition and replacing it with the word “unsecured”;

(b)the definition of “Senior Debt Rating” in Section 1.01 of the HoldCo Acquisition Credit Agreement is amended by deleting the word “secured” where it appears in such definition and replacing it with the word “unsecured”; and

(c)Section 5.13 of the HoldCo Acquisition Credit Agreement is amended by deleting the word “secured” where it appears in such provision and replacing it with the word “unsecured”.

Section 2.4As consideration for this Consent and the release of the security interests and Liens of the Lenders and the Administrative Agent relating to the Released

2 Cleco - Consent to HoldCo Acquisition Credit Agreement

Collateral as set forth herein, the Borrower will pay a fee to each Lender in an amount equal to fifteen (15) basis points of such Lender’s Revolving Loan Commitment as of the Effective Date under the HoldCo Acquisition Credit Agreement (collectively, the “Consent Fee”).

Article III.

CONDITIONS TO EFFECTIVENESS

Section 3.1This Consent shall become effective on and as of the date (the “Effective Date”) on which each of the following conditions precedent shall have been satisfied in full:

(a)the Administrative Agent shall have received counterparts of this Consent executed by the Borrower, all Lenders and the Administrative Agent;

(b)the Borrower shall have paid the Consent Fee; and

(c)the Administrative Agent and the Borrower shall have received a copy of the certificate of the Borrower dated the Effective Date (the “Indenture Collateral Release Certificate”), duly signed by the Borrower and the Intercreditor Agent (as defined in the Pari Passu Intercreditor Agreement), required to be delivered by the Borrower to Wells Fargo Bank, N.A., as trustee (in such capacity, the “Trustee”), pursuant to Section 12.03(a) of that certain Indenture, dated as of May 17, 2016 (as amended, restated, supplemented or otherwise modified from time to time, the “Indenture”), to confirm that the conditions set forth in Section 12.03(a) of the Indenture have been satisfied.

Article IV.

COVENANT

Section 4.1The Borrower shall promptly, but no later than three Business Days, after the Effective Date provide evidence reasonably satisfactory to the Administrative Agent that the Borrower has delivered to the Trustee the Indenture Collateral Release Certificate. The Borrower agrees and confirms that failure to deliver the Indenture Collateral Release Certificate to the Trustee in accordance with the preceding sentence shall constitute an immediate Event of Default under the HoldCo Acquisition Credit Agreement.

Article V.

REPRESENTATIONS AND WARRANTIES

Section 5.1In order to induce each of the Lenders and the Administrative Agent to provide this Consent, the Borrower represents and warrants as of the date hereof and as of the Effective Date, which representations and warranties shall survive the execution of this Consent and the Effective Date, that:

(a)all necessary action on the part of the Borrower required to authorize the execution, delivery and performance of this Consent has been duly and effectively taken;

3 Cleco - Consent to HoldCo Acquisition Credit Agreement

(b)the execution, delivery and performance of this Consent has been duly authorized by all necessary action on the part of the Borrower, and this Consent has been executed and delivered by the Borrower and constitutes the legal, valid and binding obligations of the Borrower, enforceable against the Borrower in accordance with the terms thereof, except as may be limited by applicable bankruptcy, insolvency, reorganization, moratorium, fraudulent conveyance or similar laws affecting the rights of creditors generally and subject to general principles of equity (regardless of whether considered in equity or at law);

(c)none of the execution, delivery or performance by the Borrower of this Consent (i) violates, contravenes or conflicts with the terms of the Borrower’s Constitutive Documents or (ii) violates or constitutes a default or requires consent (except for such consents that have been obtained or are not required at the date this representation is made or repeated) by the Borrower under any material Governmental Rule applicable to the Borrower or any other material contractual obligation to which the Borrower or any such Subsidiary is a party, except for, with respect solely to clause (ii) hereof, for any defaults or violations or consents that would not reasonably be expected to result in a Material Adverse Effect;

(d)after giving effect to this Consent, no Indebtedness of the Borrower will be secured by the Released Collateral, other than the Indebtedness issued pursuant to the Indenture; and

(e)no Default or Event of Default has occurred and is continuing.

Article VI.

GENERAL PROVISIONS

Section 6.1Reference to the Effect on the Financing Documents.

(a)On and after the Effective Date, each reference in the HoldCo Acquisition Credit Agreement to “this Agreement”, “hereunder”, “hereof” or words of like import referring to the HoldCo Acquisition Credit Agreement, and each reference in each other Financing Document to “the HoldCo Acquisition Credit Agreement”, “the Acquisition Facilities Credit Agreement”, “thereunder”, “thereof” or words of like import referring to the HoldCo Acquisition Credit Agreement, shall mean and be a reference to the HoldCo Acquisition Credit Agreement, as amended by this Consent.

(b)Except as specifically provided above, all of the terms and provisions of the HoldCo Acquisition Credit Agreement and all other Financing Documents are and shall remain in full force and effect and are hereby ratified and confirmed.

(c)The execution, delivery and effectiveness of this Consent shall not, except as expressly provided herein, operate as a waiver or amendment of any right, power or remedy of the Lenders or the Administrative Agent under any of the Financing

4 Cleco - Consent to HoldCo Acquisition Credit Agreement

Documents, nor constitute a waiver or amendment of any other provision of any of the Financing Documents or for any purpose except as expressly set forth herein.

(d)This Consent is a Financing Document.

Section 6.2No Oral Modification. This Consent may not be amended, supplemented, modified or waived, except in accordance with the Financing Documents.

Section 6.3Binding Upon Successors and Assigns. This Consent shall inure to the benefit of, and shall be binding upon, the parties hereto and their respective successors and permitted assigns under the Financing Documents.

Section 6.4Execution in Counterparts. This Consent may be executed in several counterparts, each of which is an original (and by different parties hereto in different counterparts), but all of which together constitute one and the same agreement. This Consent and the other Financing Documents constitute the entire contract among the parties relating to the subject matter hereof and supersedes any and all previous agreement and understanding, oral or written, relating to the subject matter hereof. Delivery of an executed counterpart of a signature page of this Consent by facsimile or other electronic imaging means (e.g. “pdf” or “tif”) shall be effective as delivery of a manually executed counterpart of this Consent.

Section 6.5Notices; Applicable Law and Jurisdiction. The provisions set forth in Sections 9.01 (Notices), 9.02 (Waivers; Amendments), 9.03 (Expenses; Indemnity; Damage Waiver), 9.05 (Survival), 9.07 (Severability), 9.09 (Governing Law; Jurisdiction; Consent to Service of Process), 9.10 (WAIVER OF JURY TRIAL), 9.11 (Headings) and 9.12 (Confidentiality) of the HoldCo Acquisition Credit Agreement shall apply to this Consent and are hereby incorporated by reference, mutatis mutandis, with the same force and effect as if fully set forth in this Consent (and as if each reference to “this Agreement” were a reference to this Consent).

Section 6.6Instruction to Administrative Agent. The Lenders, the Issuing Bank and the Swingline Lender hereby instruct the Administrative Agent to direct the Intercreditor Agent and the Collateral Agent under the Pari Passu Intercreditor Agreement to execute and deliver Amendment No. 1 to the Pari Passu Intercreditor Agreement in substantially the form attached hereto as Exhibit A.

[Signature Pages Follow]

5 Cleco - Consent to HoldCo Acquisition Credit Agreement

IN WITNESS WHEREOF, this Consent has been executed by the undersigned as of the date first set forth above.

CLECO CORPORATE HOLDINGS LLC, as Borrower
By	/s/ Terry L. Taylor
Name:	Terry L. Taylor
Title:	Chief Financial Officer
By	/s/ Julia E. Callis
Name:	Julia E. Callis
Title:	Chief Compliance Officer & General Counsel

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

CANADIAN IMPERIAL BANK OF COMMERCE, NEW YORK BRANCH, as a Lender
By:	/s/ Anju Abraham
Name:	Anju Abraham
Title:	Authorized Signatory
By:	/s/ Gordon R. Eadon
Name:	Gordon R. Eadon
Title:	Authorized Signatory

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

CREDIT AGRICOLE CORPORATE AND INVESTMENT BANK, as a Lender
By:	/s/ Dixon Schultz
Name:	Dixon Schultz
Title:	Managing Director
By:	/s/ Nimisha Srivastav
Name:	Nimisha Srivastav
Title:	Director

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

MIZUHO BANK, LTD., as Issuing Bank, Lender and Swingline Lender
By:	/s/ Tracy Rahn
Name:	Tracy Rahn
Title:	Authorized Signatory

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

SUMITOMO MITSUI BANKING CORPORATION, as a Lender
By:	/s/ James D. Weinstein
Name:	James D. Weinstein
Title:	Managing Director

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

THE BANK OF NOVA SCOTIA, as a Lender
By:	/s/ David Dewar
Name:	David Dewar
Title:	Director

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

WELLS FARGO BANK, N.A. , as a Lender
By:	/s/ Jesse Tannuzzo
Name:	Jesse Tannuzzo
Title:	Vice President

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

COBANK, ACB, as a Lender
By:	/s/ Josh Batchelder
Name:	Josh Batchelder
Title:	Managing Director

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

JPMORGAN CHASE BANK, N.A., as a Lender
By:	/s/ Helen D. Davis
Name:	Helen D. Davis
Title:	Executive Director

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

MIZUHO BANK, LTD., as Administrative Agent
By:	/s/ Tracy Rahn
Name:	Tracy Rahn
Title:	Authorized Signatory

Signature Page to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

Exhibit A

Amendment No. 1 to Pari Passu Intercreditor Agreement

[Attached]

Exhibit A to Consent to the Release of Collateral (HoldCo Acquisition Credit Agreement)

EX-12.A

CLECO CORPORATE HOLDINGS LLC EXHIBIT 12(a)

Computation of Ratios of Earnings to Fixed Charges (Unaudited)
	SUCCESSOR(1)									PREDECESSOR(2)
(THOUSANDS, EXCEPT RATIOS)	FOR THE SIX MONTHS ENDED JUNE 30, 2018			FOR THE TWELVE MONTHS ENDED DEC. 31, 2017			APR. 13, 2016 - DEC. 31, 2016			JAN. 1, 2016 - APR. 12, 2016			FOR THE TWELVE MONTHS ENDED DEC. 31, 2015			FOR THE TWELVE MONTHS ENDED DEC. 31, 2014
Net income (loss)	$	36,700		$	138,080		$	(24,113	)	$	(3,960	)	$	133,669		$	154,739
Income tax expense (benefit)	10,528			7,079			(22,822		)	3,468			77,704			67,116
Undistributed equity loss from investees	—			—			—			—			7			—
Amortization of capitalized interest	—			—			—			—			—			77
Total fixed charges (from below)	65,917			126,303			91,338			22,547			79,795			76,163
Total earnings	$	113,145		$	271,462		$	44,403		$	22,055		$	291,175		$	298,095
Fixed charges
Interest	$	61,997		$	118,775		$	87,315		$	21,491		$	75,535		$	71,959
Amortization of debt expense, premium, net	2,991			6,425			3,537			839			3,342			3,227
Portion of rentals representative of an interest factor(3)	502			1,062			362			146			572			489
Interest of capitalized lease	427			41			124			71			346			488
Total fixed charges	$	65,917		$	126,303		$	91,338		$	22,547		$	79,795		$	76,163
Ratio of earnings to fixed charges	1.72		x	2.15		x	(4)			(4)			3.65		x	3.91		x
(1) Successor is the post-merger activity of Cleco. Cleco has accounted for the Merger transaction by applying the acquisition method of accounting. The successor period is not comparable to the predecessor  period. (2) Predecessor is the pre-merger activity of Cleco. Cleco has accounted for the Merger transaction by applying the acquisition method of accounting. The predecessor period is not comparable to the successor  period. (3) Interest portion of rental expenses, that cannot be imputed, is estimated to equal 11% of such expense, and the imputed interest portion of rental expenses is calculated between 3.62% and 6.08% of such  expenses, which are considered reasonable approximations of the interest factors. (4) Earnings were inadequate to cover fixed charges. The earnings did not cover the fixed charges by $46.9 million and $0.5 million for the successor period April 13, 2016, through December 31, 2016, and the  predecessor period January 1, 2016, through April 12, 2016, respectively.

EX-12.B

CLECO POWER LLC EXHIBIT 12(b)

Computation of Ratios of Earnings to Fixed Charges (Unaudited)
(THOUSANDS, EXCEPT RATIOS)	FOR THE SIX MONTHS ENDED JUNE 30, 2018			FOR THE TWELVE MONTHS ENDED DEC. 31, 2017			FOR THE TWELVE MONTHS ENDED DEC. 31, 2016			FOR THE TWELVE MONTHS ENDED DEC. 31, 2015			FOR THE TWELVE MONTHS ENDED DEC. 31, 2014
Net income	$	69,024		$	150,738		$	39,128		$	141,350		$	154,316
Income tax expense	21,707			67,331			18,369			79,294			76,974
Total fixed charges (from below)	38,613			72,752			78,442			78,364			77,230
Total earnings	$	129,344		$	290,821		$	135,939		$	299,008		$	308,520
Fixed charges
Interest	$	35,332		$	66,491		$	74,450		$	74,394		$	73,140
Amortization of debt expense, premium, net	2,352			5,158			3,289			3,052			3,113
Portion of rentals representative of an interest factor*	502			1,062			508			572			489
Interest of capitalized lease	427			41			195			346			488
Total fixed charges	$	38,613		$	72,752		$	78,442		$	78,364		$	77,230
Ratio of earnings to fixed charges	3.35		x	4.00		x	1.73		x	3.82		x	3.99		x
* Interest portion of rental expenses, that cannot be imputed, is estimated to equal 11% of such expense, and the imputed interest portion of rental expenses is calculated between 3.62% and 6.08% of such expenses, which are considered reasonable approximations of the interest factors.

EX-31.1

CLECO CORPORATE HOLDINGS LLC EXHIBIT 31.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, William G. Fontenot, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2018, of Cleco Corporate Holdings LLC;

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

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

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

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

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

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

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

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

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

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

Date:   August 1, 2018

/s/ William G. Fontenot

William G. Fontenot

President and Chief Executive Officer

EX-31.2

CLECO CORPORATE HOLDINGS LLC EXHIBIT 31.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, Terry L. Taylor, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2018, of Cleco Corporate Holdings LLC;

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

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

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

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

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

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

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

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

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

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

Date:   August 1, 2018

/s/  Terry L. Taylor

Terry L. Taylor

Chief Financial Officer

EX-31.3

CLECO POWER LLC          EXHIBIT 31.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, William G. Fontenot, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2018, of Cleco Power LLC;

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

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

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

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

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

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

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

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

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

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

Date:  August 1, 2018

/s/  William G. Fontenot

William G. Fontenot

President and Chief Executive Officer

EX-31.4

CLECO POWER LLC          EXHIBIT 31.4

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO SECTION 302

OF THE SARBANES-OXLEY ACT OF 2002

I, Terry L. Taylor, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended June 30, 2018, of Cleco Power LLC;

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

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

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

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

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

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

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

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

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

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

Date:   August 1, 2018

/s/  Terry L. Taylor

Terry L. Taylor

Chief Financial Officer

EX-32.1

CLECO CORPORATE HOLDINGS LLC EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Corporate Holdings LLC (the “Company”) on Form 10-Q for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William G. Fontenot, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:   August 1, 2018

/s/  William G. Fontenot

William G. Fontenot

President and Chief Executive Officer

EX-32.2

CLECO CORPORATE HOLDINGS LLC EXHIBIT 32.2

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Corporate Holdings LLC (the “Company”) on Form 10-Q for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Terry L. Taylor, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:  August 1, 2018

/s/  Terry L. Taylor

Terry L. Taylor

Chief Financial Officer

EX-32.3

CLECO POWER LLC EXHIBIT 32.3

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Power LLC (the “Company”) on Form 10-Q for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William G. Fontenot, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:   August 1, 2018

/s/  William G. Fontenot

William G. Fontenot

President and Chief Executive Officer

EX-32.4

CLECO POWER LLC EXHIBIT 32.4

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Power LLC (the “Company”) on Form 10-Q for the quarter ended June 30, 2018, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Terry L. Taylor, Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:  August 1, 2018

/s/  Terry L. Taylor

Terry L. Taylor

Chief Financial Officer

EX-95

CLECO CORPORATE HOLDINGS LLC
CLECO POWER LLC	EXHIBIT 95

MINE SAFETY DISCLOSURES

Cleco Power does not have control over the day-to-day operations, including safety, of either the Dolet Hills Mine or the Oxbow Mine. Pursuant to a mining joint operating agreement governing the mines, Cleco Power and SWEPCO each have two representatives on a four member executive committee. The main purpose of the executive committee is to enhance communication among the mine operator, Cleco Power, and SWEPCO. The executive committee’s duties include: reviewing the status of the mine; providing policy recommendations concerning basic planning, land acquisition, geological and engineering activities; recommending economic limits and personnel requirements; reviewing mining and lignite delivery issues; and reviewing the financial information and operational records of DHLC.

Under Section 1503 of the Dodd-Frank Act, public reporting companies that meet the definition of an “operator” of a mine under the Federal Mine Safety and Health Act of 1977 (Mine Act) as administered by the Mine Safety and Health Administration (MSHA) are required to report notices of violations and proposed assessments of violations of MSHA regulations promulgated in support of the Mine Act. The MSHA defines an operator as any owner, lessee, or other person who operates, controls, or supervises a coal or other mine or any independent contractor performing services or construction at such mine. Cleco Power might meet the definition of an “operator” under the Mine Act through its two representatives on the executive committee. Therefore, Cleco Power has chosen to include the disclosures required by Section 1503 of the Dodd-Frank Act.

During the second quarter of 2018, DHLC was issued six safety citations by MSHA. While five of the citations were classified as non Significant and Substantial and are not subject to MSHA’s reporting requirements, one was classified as Significant and Substantial. One of the five non Significant and Substantial safety citations was assessed by MSHA and paid during the second quarter of 2018. This amount was considered immaterial. Also in the second quarter of 2018, three Significant and Substantial citations and one non Significant and Substantial citation that were issued to DHLC in the first quarter were assessed and paid. The amounts were considered immaterial.

The MSHA definition of control is not the same as the definition of control pursuant to accounting pronouncements relating to consolidation and equity method investments. Management has determined that its relationship with DHLC does not meet the definition of control under authoritative guidance; therefore, Cleco Power has not included any financial information about DHLC in its periodic reports.

XML

Document And Entity Information - shares	6 Months Ended
	Jun. 30, 2018	Aug. 01, 2018
Entity Information [Line Items]
Entity Registrant Name	Cleco Corporate Holdings LLC
Entity Central Index Key	0001089819
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-Q
Document Period End Date	Jun. 30, 2018
Document Fiscal Year Focus	2018
Document Fiscal Period Focus	Q2
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	0000018672
Entity Filer Category	Non-accelerated Filer

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Condensed Consolidated Statements of Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Operating revenue
Electric operations	$ 294,213	$ 287,435	$ 556,424	$ 521,491
Other operations	18,685	21,465	40,881	38,345
Affiliate revenue	0	0	0	0
Gross operating revenue	312,898	308,900	597,305	559,836
Electric customer credits	(13,637)	(239)	(21,284)	(674)
Operating revenue, net	299,261	308,661	576,021	559,162
Operating expenses
Fuel used for electric generation	77,562	87,974	144,578	157,846
Power purchased for utility customers	50,154	43,356	103,313	75,320
Other operations	30,511	26,235	58,477	55,561
Maintenance	24,192	24,400	53,311	48,924
Depreciation and amortization	41,807	41,552	84,314	82,402
Taxes other than income taxes	11,326	11,874	23,584	24,376
Total operating expenses	235,552	235,391	467,577	444,429
Operating income	63,709	73,270	108,444	114,733
Interest income	1,427	381	2,211	693
Allowance for equity funds used during construction	3,224	1,440	5,587	2,350
Other income	798	475	981	1,845
Other expense	(3,745)	(3,281)	(6,928)	(6,219)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	32,957	31,022	64,988	62,967
Allowance for borrowed funds used during construction	(1,048)	(401)	(1,921)	(628)
Total interest charges	31,909	30,621	63,067	62,339
Income before income taxes	33,504	41,664	47,228	51,063
Federal and state income tax expense	7,665	16,220	10,528	19,327
Net income	25,839	25,444	36,700	31,736
CLECO POWER
Operating revenue
Electric operations	296,633	289,855	561,264	527,408
Other operations	18,685	20,950	40,880	37,315
Affiliate revenue	220	221	428	440
Gross operating revenue	315,538	311,026	602,572	565,163
Electric customer credits	(13,637)	(239)	(21,284)	(674)
Operating revenue, net	301,901	310,787	581,288	564,489
Operating expenses
Fuel used for electric generation	77,562	87,974	144,578	157,846
Power purchased for utility customers	50,154	43,356	103,313	75,320
Other operations	26,812	27,649	54,116	57,913
Maintenance	24,138	24,264	53,216	48,684
Depreciation and amortization	39,720	39,473	80,109	78,230
Taxes other than income taxes	10,913	11,404	22,831	23,404
Total operating expenses	229,299	234,120	458,163	441,397
Operating income	72,602	76,667	123,125	123,092
Interest income	1,313	328	1,953	594
Allowance for equity funds used during construction	3,224	1,440	5,587	2,350
Other income	797	165	1,537	375
Other expense	(3,099)	(2,393)	(5,708)	(4,391)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	19,155	17,812	37,684	36,143
Allowance for borrowed funds used during construction	(1,048)	(401)	(1,921)	(628)
Total interest charges	18,107	17,411	35,763	35,515
Income before income taxes	56,730	58,796	90,731	86,505
Federal and state income tax expense	13,710	23,063	21,707	32,918
Net income	$ 43,020	$ 35,733	$ 69,024	$ 53,587

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net income	$ 25,839	$ 25,444	$ 36,700	$ 31,736
Other comprehensive income, net of tax
Postretirement benefits (loss) gain, net of tax	247	60	290	(2,131)
Total other comprehensive income, net of tax	247	60	290	(2,131)
Comprehensive income, net of tax	26,086	25,504	36,990	29,605
CLECO POWER
Net income	43,020	35,733	69,024	53,587
Other comprehensive income, net of tax
Postretirement benefits (loss) gain, net of tax	267	193	500	(227)
Amortization of interest rate derivatives to earnings	64	53	128	106
Total other comprehensive income, net of tax	331	246	628	(121)
Comprehensive income, net of tax	$ 43,351	$ 35,979	$ 69,652	$ 53,466

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - (Parenthetical) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Net tax expense (benefit) of gain (loss) on postretirement benefits	$ 87	$ 37	$ 102	$ (1,333)
CLECO POWER
Net tax expense (benefit) of gain (loss) on postretirement benefits	94	120	177	(142)
Net tax expense (benefit) of derivatives qualifying as hedges	$ 22	$ 33	$ 45	$ 66

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Condensed Consolidated Balance Sheets (Unaudited) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets
Cash and cash equivalents	$ 116,312	$ 119,040
Restricted cash and cash equivalents	9,945	13,081
Customer accounts receivable (less allowance for doubtful accounts)	65,886	60,117
Other accounts receivable	24,648	30,806
Unbilled revenue	46,480	36,398
Fuel inventory, at average cost	78,621	87,520
Materials and supplies, at average cost	87,927	85,404
Energy risk management assets	26,077	7,396
Accumulated deferred fuel	36,786	13,980
Cash surrender value of company-/trust-owned life insurance policies	83,365	83,117
Prepayments	8,249	9,050
Regulatory assets	21,361	24,670
Other current assets	1,749	1,146
Total current assets	607,406	571,725
Property, plant, and equipment
Property, plant, and equipment	3,691,344	3,594,525
Accumulated depreciation	(251,348)	(192,348)
Net property, plant, and equipment	3,439,996	3,402,177
Construction work in progress	238,218	186,629
Total property, plant, and equipment, net	3,678,214	3,588,806
Equity investment in investee	18,172	18,172
Goodwill	1,490,797	1,490,797
Restricted cash and cash equivalents	19,080	20,081
Regulatory assets	417,849	432,358
Intangible assets	99,889	114,850
Other deferred charges	54,204	41,593
Total assets	6,385,611	6,278,382
Current liabilities
Long-term debt due within one year	20,405	19,193
Accounts payable	145,459	147,562
Customer deposits	60,494	58,582
Provision for rate refund	25,311	4,206
Taxes payable, net	46,237	22,698
Interest accrued	16,024	14,703
Deferred compensation	11,500	12,132
Other current liabilities	24,027	21,278
Total current liabilities	349,457	300,354
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	624,584	614,812
Postretirement benefit obligations	243,740	242,135
Regulatory liabilities - deferred taxes, net	136,447	140,426
Restricted storm reserve	14,955	14,469
Other deferred credits	34,625	33,724
Total long-term liabilities and deferred credits	1,054,351	1,045,566
Long-term debt, net	2,888,356	2,836,105
Total liabilities	4,292,164	4,182,025
Commitments and contingencies (Note 12)
Member’s equity
Membership interest	2,069,376	2,069,376
Retained earnings	26,702	29,902
Accumulated other comprehensive loss	(2,631)	(2,921)
Total member’s equity	2,093,447	2,096,357
Total liabilities and member’s equity	6,385,611	6,278,382
CLECO POWER
Current assets
Cash and cash equivalents	71,579	69,816
Restricted cash and cash equivalents	9,945	13,081
Customer accounts receivable (less allowance for doubtful accounts)	65,886	60,117
Accounts receivable - affiliate	698	1,355
Other accounts receivable	24,149	30,680
Unbilled revenue	46,480	36,398
Fuel inventory, at average cost	78,621	87,520
Materials and supplies, at average cost	87,927	85,404
Energy risk management assets	26,077	7,396
Accumulated deferred fuel	36,786	13,980
Cash surrender value of company-/trust-owned life insurance policies	20,394	20,278
Prepayments	6,700	7,236
Regulatory assets	12,504	15,812
Other current assets	905	475
Total current assets	488,651	449,548
Property, plant, and equipment
Property, plant, and equipment	4,985,054	4,893,484
Accumulated depreciation	(1,763,394)	(1,712,590)
Net property, plant, and equipment	3,221,660	3,180,894
Construction work in progress	238,151	185,507
Total property, plant, and equipment, net	3,459,811	3,366,401
Equity investment in investee	18,172	18,172
Restricted cash and cash equivalents	19,059	20,060
Regulatory assets	248,494	257,408
Intangible assets	31,707	41,701
Other deferred charges	50,868	35,451
Total assets	4,316,762	4,188,741
Current liabilities
Long-term debt due within one year	20,405	19,193
Accounts payable	137,599	134,374
Accounts payable - affiliate	10,701	8,697
Customer deposits	60,494	58,582
Provision for rate refund	25,311	4,206
Taxes payable, net	64,562	31,611
Interest accrued	8,490	7,083
Other current liabilities	18,826	16,172
Total current liabilities	346,388	279,918
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	668,128	656,362
Postretirement benefit obligations	172,220	173,747
Regulatory liabilities - deferred taxes, net	136,447	140,426
Restricted storm reserve	14,955	14,469
Other deferred credits	31,593	31,665
Total long-term liabilities and deferred credits	1,023,343	1,016,669
Long-term debt, net	1,397,700	1,341,475
Total capitalization	2,947,031	2,892,154
Commitments and contingencies (Note 12)
Member’s equity
Total member’s equity	1,549,331	1,550,679
Total liabilities and member’s equity	$ 4,316,762	$ 4,188,741

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Condensed Consolidated Balance Sheets (Unaudited) (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Current assets
Customer accounts receivable, allowance for doubtful accounts	$ 1,054	$ 1,457
CLECO POWER
Current assets
Customer accounts receivable, allowance for doubtful accounts	$ 1,054	$ 1,457

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Condensed Consolidated Statements of Cash Flows (Unaudited) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018		Jun. 30, 2017
Operating activities
Net income	$ 36,700		$ 31,736
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	92,756		93,943
Provision for doubtful accounts	84		2,587
Unearned compensation expense	2,005		1,909
Allowance for equity funds used during construction	(5,587)		(2,350)
Deferred income taxes	5,691		16,881
Deferred fuel costs	(26,339)		(305)
Cash surrender value of company-/trust-owned life insurance	(248)		(2,393)
Changes in assets and liabilities
Accounts receivable	(8,309)		(30,205)
Unbilled revenue	(10,083)		(5,677)
Fuel inventory and materials and supplies	6,500		(9,652)
Accounts payable	306		(23,828)
Customer deposits	6,746		5,646
Provision for merger commitments	(1,847)		(6,761)
Postretirement benefit obligations	1,998		2,696
Regulatory assets and liabilities, net	7,917		4,896
Other deferred accounts	1,612		(8,631)
Taxes accrued	22,621		15,000
Interest accrued	1,321		965
Other operating	1,964		608
Net cash provided by operating activities	135,808		87,065
Investing activities
Additions to property, plant, and equipment	(135,702)		(128,693)
Allowance for equity funds used during construction	5,587		2,350
Reimbursement for property loss	1,223		105
Issuance of note receivable	(16,800)		0
Return of equity investment in tax credit fund	2,775		841
Other investing	672		328
Net cash used in investing activities	(142,245)		(125,069)
Financing activities
Draws on credit facilities	0		114,000
Payments on credit facilities	0		(29,000)
Issuances of long-term debt	50,000		0
Repayment of long-term debt	(9,700)		(9,060)
Distributions to member	(39,900)		(55,655)
Other financing	(828)		(849)
Net cash (used in) provided by financing activities	(428)		19,436
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	(6,865)		(18,568)
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	145,337	[2]	51,003
Supplementary cash flow information
Interest paid, net of amount capitalized	60,528		57,937
Income taxes paid, net	272		1
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	40,011		13,125
Non-cash additions to property, plant, and equipment	0		3,009
Incurrence of capital lease obligation - barges	16,800		0
CLECO POWER
Operating activities
Net income	69,024		53,587
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	83,199		82,292
Provision for doubtful accounts	84		2,500
Unearned compensation expense	609		1,023
Allowance for equity funds used during construction	(5,587)		(2,350)
Deferred income taxes	7,566		3,916
Deferred fuel costs	(26,339)		(305)
Changes in assets and liabilities
Accounts receivable	(7,933)		(30,240)
Accounts receivable, affiliate	1,639		1,560
Unbilled revenue	(10,083)		(5,677)
Fuel inventory and materials and supplies	6,500		(9,652)
Prepayments	65		(1,438)
Accounts payable	5,465		(21,455)
Accounts payable, affiliate	(1,740)		(58)
Customer deposits	6,746		5,646
Provision for merger commitments	(1,847)		(6,761)
Postretirement benefit obligations	1,784		2,472
Regulatory assets and liabilities, net	6,923		3,902
Other deferred accounts	1,949		(8,665)
Taxes accrued	32,033		21,753
Interest accrued	1,407		1,037
Other operating	2,317		1,436
Net cash provided by operating activities	173,781		94,523
Investing activities
Additions to property, plant, and equipment	(135,334)		(127,297)
Allowance for equity funds used during construction	5,587		2,350
Reimbursement for property loss	1,223		105
Issuance of note receivable	(16,800)		0
Other investing	672		958
Net cash used in investing activities	(144,652)		(123,884)
Financing activities
Draws on credit facilities	0		90,000
Payments on credit facilities	0		(15,000)
Issuances of long-term debt	50,000		0
Repayment of long-term debt	(9,700)		(9,060)
Distributions to member	(71,000)		(60,000)
Other financing	(803)		(595)
Net cash (used in) provided by financing activities	(31,503)		5,345
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	(2,374)		(24,016)
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	100,583	[4]	43,939
Supplementary cash flow information
Interest paid, net of amount capitalized	33,940		31,907
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	39,974		13,081
Non-cash additions to property, plant, and equipment	0		3,009
Incurrence of capital lease obligation - barges	$ 16,800		$ 0

[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 $116,312, current restricted cash and cash equivalents are $9,945, non-current restricted cash and cash equivalents are $19,080.

[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 $71,579, current restricted cash and cash equivalents are $9,945, non-current restricted cash and cash equivalents are $19,059.

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Condensed Consolidated Statements of Cash Flows (Unaudited) - (Parenthetical) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Cash and cash equivalents	$ 116,312	$ 119,040
Restricted cash and cash equivalents, current	9,945	13,081
Restricted cash and cash equivalents, noncurrent	19,080	20,081
CLECO POWER
Cash and cash equivalents	71,579	69,816
Restricted cash and cash equivalents, current	9,945	13,081
Restricted cash and cash equivalents, noncurrent	$ 19,059	$ 20,060

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Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited) - 6 months ended Jun. 30, 2018 - USD ($) $ in Thousands	Total	MEMBERSHIP INTEREST	RETAINED EARNINGS	AOCI	CLECO POWER	CLECO POWER MEMBER’S EQUITY	CLECO POWER AOCI
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	(39,900)		(39,900)		(71,000)	(71,000)
Net income	36,700		36,700		69,024	69,024
Other comprehensive income, net of tax	290			290	628		628
Balances, end of period at Jun. 30, 2018	$ 2,093,447	$ 2,069,376	$ 26,702	$ (2,631)	$ 1,549,331	$ 1,562,386	$ (13,055)

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Summary of Significant Accounting Policies

6 Months Ended

Jun. 30, 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 JUNE 30, 2018		AT DEC. 31, 2017
Current
Cleco Katrina/Rita’s storm recovery bonds	$	8,144	$	8,597
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	601		3,284
Total current	9,945		13,081
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	14,934		14,456
Cleco Power’s charitable contributions	2,933		3,575
Cleco Power’s rate credit escrow	1,192		2,029
Total non-current	19,080		20,081
Total restricted cash and cash equivalents	$	29,025	$	33,162

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current
Cleco Katrina/Rita’s storm recovery bonds	$	8,144	$	8,597
Charitable contributions	1,200		1,200
Rate credit escrow	601		3,284
Total current	9,945		13,081
Non-current
Future storm restoration costs	14,934		14,456
Charitable contributions	2,933		3,575
Rate credit escrow	1,192		2,029
Total non-current	19,059		20,060
Total restricted cash and cash equivalents	$	29,004	$	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 June 30, 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 $10.6 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 June 30, 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 each reporting period presented, the Registrants did not enter into any contracts to mitigate the volatility in interest rate risk.

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Revenue Recognition

6 Months Ended

Jun. 30, 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 revenue requirements with rates effective June 1 of each year.

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 and six months ended June 30, 2018, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	CLECO POWER			OTHER				ELIMINATIONS			TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	107,805		$	—			$	—		$	107,805
Commercial (1)	71,865			—				—			71,865
Industrial (1)	40,679			—				—			40,679
Other retail (1)	3,793			—				—			3,793
Surcharge	6,193			—				—			6,193
Total retail revenue	$	230,335		$	—			$	—		$	230,335
Wholesale, net (1)	54,662			(2,420		)	(2)	—			52,242
Transmission	11,943			—				—			11,943
Other (3)	(6,895		)	—				—			(6,895		)
Total revenue from contracts with customers	$	290,045		$	(2,420	)		$	—		$	287,625
Revenue unrelated to contracts with customers
Affiliate	$	220		$	17,273			$	(17,493	)	$	—
Other	11,636			—				—			11,636
Total revenue unrelated to contracts with customers	11,856			17,273				(17,493		)	11,636
Operating revenue, net	$	301,901		$	14,853			$	(17,493	)	$	299,261

⁽¹⁾ Includes fuel recovery revenue.

⁽²⁾ Amortization of intangible assets related to wholesale power supply agreements.

⁽³⁾ Other revenue from contracts with customers includes $13.6 million of electric customer credits, partially offset by $4.1 million of other miscellaneous fee revenue, and $2.6 million of Teche Unit 3 SSR revenue, net of $0.3 million of reserves for capital expenditures.

	FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	CLECO POWER			OTHER				ELIMINATIONS			TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	199,195		$	—			$	—		$	199,195
Commercial (1)	138,560			—				—			138,560
Industrial (1)	78,065			—				—			78,065
Other retail (1)	7,594			—				—			7,594
Surcharge	11,431			—				—			11,431
Total retail revenue	$	434,845		$	—			$	—		$	434,845
Wholesale, net (1)	101,631			(4,840		)	(2)	—			96,791
Transmission	26,448			—				—			26,448
Other (3)	(6,852		)	1				—			(6,851		)
Total revenue from contracts with customers	$	556,072		$	(4,839	)		$	—		$	551,233
Revenue unrelated to contracts with customers
Affiliate	$	428		$	32,942			$	(33,370	)	$	—
Other	24,788			—				—			24,788
Total revenue unrelated to contracts with customers	25,216			32,942				(33,370		)	24,788
Operating revenue, net	$	581,288		$	28,103			$	(33,370	)	$	576,021

⁽¹⁾ Includes fuel recovery revenue.

⁽²⁾ Amortization of intangible assets related to wholesale power supply agreements.

⁽³⁾ Other revenue from contracts with customers includes $21.3 million of electric customer credits, partially offset by $8.6 million of other miscellaneous fee revenue, and $5.8 million of Teche Unit 3 SSR revenue, net of $2.2 million of reserves for capital expenditures.

Transaction Price Allocated to Remaining Performance Obligations

For 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 June 30, 2018, and (2) when Cleco expects to recognize this revenue:

REMAINING PERFORMANCE OBLIGATIONS	(THOUSANDS)
Six months ending Dec. 31, 2018	$	24,213
Years ending Dec. 31,
2019	23,874
2020	7,068
2021	7,068
2022	6,468
Thereafter	10,210
Total remaining performance obligations	$	78,901

Unsatisfied performance obligations primarily relate to stand-ready obligations as part of fixed capacity minimums.

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Recent Authoritative Guidance

6 Months Ended

Jun. 30, 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 SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Transfer of cash from restricted accounts, net	$	6,003		$	—
Net cash used in investing activities	$	(119,066	)	$	(125,069	)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	$	(12,565	)	$	(18,568	)
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	$	10,512		$	51,003

Cleco Power
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Transfer of cash from restricted accounts, net	$	6,003		$	—
Net cash used in investing activities	$	(117,881	)	$	(123,884	)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	$	(18,013	)	$	(24,016	)
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	$	3,469		$	43,939

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 JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	29,256		$	26,235
Total operating expenses	$	238,412		$	235,391
Operating income	$	70,249		$	73,270
Other expense	$	(260	)	$	(3,281	)

Cleco
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	61,244		$	55,561		*
Total operating expenses	$	450,114		$	444,429
Operating income	$	109,048		$	114,733
Other expense	$	(534	)	$	(6,219	)
* Also reflects less than $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 JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	29,782		$	27,649
Total operating expenses	$	236,253		$	234,120
Operating income	$	74,534		$	76,667
Other expense	$	(260	)	$	(2,393	)

Cleco Power
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	61,770		$	57,913
Total operating expenses	$	445,254		$	441,397
Operating income	$	119,235		$	123,092
Other expense	$	(534	)	$	(4,391	)

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.

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Regulatory Assets and Liabilities

6 Months Ended

Jun. 30, 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 JUNE 30, 2018			AT DEC. 31, 2017
Regulatory liabilities - deferred taxes, net	$	(136,447	)	$	(140,426	)
Mining costs	2,549			3,823
Interest costs	4,340			4,499
AROs	2,824			2,762
Postretirement costs	136,644			142,764
Tree trimming costs	8,015			7,193
Training costs	6,474			6,552
Surcredits, net	289			2,173
AMI deferred revenue requirement	3,954			4,227
Emergency declarations	3,781			4,131
Production operations and maintenance expenses	5,827			8,625
AFUDC equity gross-up	71,295			71,205
Acadia Unit 1 acquisition costs	2,283			2,336
Financing costs	8,108			8,293
MISO integration costs	—			468
Coughlin transaction costs	953			968
Corporate franchise tax, net	1,500			153
MATS costs	—			2,564
Non-service cost of postretirement benefits	2,136			—
Other	26			484
Total regulatory assets	260,998			273,220
Accumulated deferred fuel	36,786			13,980
Total regulatory assets, net	$	161,337		$	146,774

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

(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Total Cleco Power regulatory assets, net	$	161,337	$	146,774
Cleco Merger adjustments (1)
Fair value of long-term debt	142,922		147,145
Postretirement costs	20,381		21,375
Financing costs	8,450		8,623
Debt issuance costs	6,459		6,665
Total Cleco regulatory assets, net	$	339,549	$	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 are being deferred to a regulatory asset and will be 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.”

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Fair Value Accounting

6 Months Ended

Jun. 30, 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 June 30, 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 JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,903,190	$	2,865,196	$	2,866,955	$	2,921,325

* The carrying value of long-term debt does not include deferred issuance costs of $11.1 million and $11.6 million at June 30, 2018, and December 31, 2017, respectively.

Cleco Power
	AT JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,410,267	$	1,518,752	$	1,369,810	$	1,535,234

* The carrying value of long-term debt does not include deferred issuance costs of $8.8 million and $9.1 million at June 30, 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 JUNE 30, 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	$	141,290	$	—	$	141,290	$	—	$	144,302	$	—	$	144,302	$	—
FTRs	26,077		—		—		26,077		7,396		—		—		7,396
Total assets	$	167,367	$	—	$	141,290	$	26,077	$	151,698	$	—	$	144,302	$	7,396
Liability description
FTRs	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352
Total liabilities	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352

Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE
(THOUSANDS)	AT JUNE 30, 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	$	96,568	$	—	$	96,568	$	—	$	95,681	$	—	$	95,681	$	—
FTRs	26,077		—		—		26,077		7,396		—		—		7,396
Total assets	$	122,645	$	—	$	96,568	$	26,077	$	103,077	$	—	$	95,681	$	7,396
Liability description
FTRs	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352
Total liabilities	$	944	$	—	$	—	$	944	$	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 JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018			2017
Beginning balance	$	4,283		$	4,418		$	7,044		$	7,683
Unrealized gains (losses)*	2,420			(2,460		)	2,420			(2,460		)
Purchases	25,112			22,843			25,483			23,118
Settlements	(6,682		)	(6,858		)	(9,814		)	(10,398		)
Ending balance	$	25,133		$	17,943		$	25,133		$	17,943
* 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 June 30, 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 June 30, 2018	$	26,077	$	944	RTO auction pricing	FTR price - per MWh	$	(3.84	)	$	7.42
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 June 30, 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 $112.5 million, $9.9 million, and $18.9 million, respectively, at June 30, 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 $67.8 million, $9.9 million, and $18.9 million, respectively, at June 30, 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 six months ended June 30, 2018, and the year ended December 31, 2017, Cleco did not 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 June 30, 2018, and December 31, 2017:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2018		AT DEC. 31, 2017
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	26,077	$	7,396
Current	Other current liabilities	944		352
Commodity-related contracts, net		$	25,133	$	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 six months ended June 30, 2018, and 2017:

	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	DERIVATIVES LINE ITEM	2018			2017			2018			2017
Commodity contracts
FTRs(1)	Electric operations	$	17,841		$	11,947		$	35,991		$	21,110
FTRs(1)	Power purchased for utility customers	(7,027		)	(6,327		)	(12,693		)	(10,992		)
Total		$	10,814		$	5,620		$	23,298		$	10,118

⁽¹⁾ For the three and six months ended June 30, 2018, unrealized gains associated with FTRs of $2.4 million were reported through Accumulated deferred fuel on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. For the three and six months ended June 30, 2017, unrealized losses associated with FTRs of $2.5 million 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 June 30, 2018, and December 31, 2017, was 19.3 million MWh and 9.0 million MWh, respectively.

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Debt

6 Months Ended

Jun. 30, 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 an aggregate principal amount of $175.0 million of senior notes. The senior notes were issued in two tranches. The first tranche was issued on December 18, 2017, with a principal amount 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 a principal amount of $50.0 million at an interest rate of 3.17%, with a final maturity date of December 16, 2024. The proceeds from the issuances and sales 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.”

On July 31, 2018, Cleco amended its $300.0 million bank term loan agreement and its $100.0 million revolving credit facility agreement to release any and all collateral from all of its debt obligations under those agreements. As a result of the release of collateral, Cleco Holdings expects Moody’s and Fitch to update Cleco Holdings’ senior debt rating. For more information on Cleco’s credit ratings and their impacts, see Note 12 — “Litigation, Other Commitment and Contingencies, and Disclosures about Guarantees — Risks and Uncertainties.”

On April 2, 2018, Cleco Power entered into a capital lease agreement for use of 42 dedicated barges to transport petroleum coke and limestone to Madison Unit 3. For more information on the capital lease agreement, see Note 12 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — Fuel Transportation Agreement.”

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Pension Plan and Employee Benefits

6 Months Ended

Jun. 30, 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 contributions 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 assumed discount rate, changes in the funding regulations, and actual returns on fund assets. Cleco Power is the plan sponsor and Support Group is 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 and six months ended June 30, 2018, and 2017 were as follows:

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED JUNE 30,						FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018		2017
Components of periodic benefit costs
Service cost	$	2,361		$	2,295		$	338	$	385
Interest cost	5,472			5,467			357		402
Expected return on plan assets	(5,938		)	(5,895		)	—		—
Amortizations
Prior period service credit	(18		)	(18		)	—		—
Net loss (gain)	2,960			2,591			5		(2		)
Net periodic benefit cost	$	4,837		$	4,440		$	700	$	785

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE SIX MONTHS ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018		2017
Components of periodic benefit costs
Service cost	$	4,753		$	4,520		$	675	$	770
Interest cost	10,654			10,824			715		805
Expected return on plan assets	(11,875		)	(12,032		)	—		—
Amortizations
Prior period service credit	(36		)	(36		)	—		—
Net loss (gain)	5,921			5,004			10		(5		)
Net periodic benefit cost	$	9,417		$	8,280		$	1,400	$	1,570

Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2018, was $0.5 million and $1.0 million, respectively. The expense of the pension plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2017, was $0.5 million and $0.9 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 and six months ended June 30, 2018, was $0.8 million and $1.6 million, respectively. The expense related to Other Benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2017, was $0.9 million and $1.7 million, respectively. The current and non-current portions of the Other Benefits liability for Cleco and Cleco Power at June 30, 2018, and December 31, 2017, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	4,061	$	4,061
Non-current	$	38,270	$	39,142

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	3,525	$	3,525
Non-current	$	33,302	$	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 the plan sponsor and Support Group is the plan administrator.

The non-service components of net periodic benefit cost related to SERP are included in Other expense within Cleco and Cleco Power’s Condensed Consolidated Statements of Income. Net periodic benefit cost related to SERP for the three and six months ended June 30, 2018, and 2017 were as follows:

	FOR THE THREE MONTHS  ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018			2017
Components of periodic benefit costs
Service cost	$	166		$	102		$	271		$	247
Interest cost	1,004			820			1,764			1,620
Amortizations
Prior period service credit	(47		)	(29		)	(81		)	(68		)
Net loss	647			624			1,232			1,025
Net periodic benefit cost	1,770			1,517			3,186			2,824
Special/contractual termination benefits	—			—			—			315
Total benefit cost	$	1,770		$	1,517		$	3,186		$	3,139

There was a remeasurement of SERP in March 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 for the three and six months ended June 30, 2018, was $0.4 million and $0.7 million, respectively. The total expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for the three and six months ended June 30, 2017, was $0.3 million and $0.6 million, respectively.

Liabilities relating to SERP are reported on the individual subsidiaries’ financial statements. The current and non-current portions of the SERP liability for Cleco and Cleco Power at June 30, 2018, and December 31, 2017, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	4,471	$	4,471
Non-current	$	79,487	$	79,868

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	929	$	929
Non-current	$	12,934	$	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 and six monthsended June 30, 2018, and 2017 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
401(k) Plan expense	$	1,229	$	1,204	$	3,292	$	2,872

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and six months ended June 30, 2018, and 2017 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
401(k) Plan expense	$	209	$	198	$	611	$	477

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Income Taxes

6 Months Ended

Jun. 30, 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 and six months ended June 30, 2018, and 2017:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2018		2017		2018		2017
Effective tax rate	22.9	%	38.9	%	22.3	%	37.8	%

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2018		2017		2018		2017
Effective tax rate	24.2	%	39.2	%	23.9	%	38.1	%

For the three and six months ended June 30, 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 June 30, 2018, and December 31, 2017, Cleco and Cleco Power had no interest payable related to uncertain tax positions. For the six months ended June 30, 2018, and 2017, Cleco and Cleco Power had no interest expense related to uncertain tax positions.

At June 30, 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 June 30, 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 six months ended June 30, 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 of 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 has issued guidance which clarifies accounting for income taxes if information is not yet available or complete. The SEC 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 impacts of the TCJA also decreased the ADIT liability for Cleco and Cleco Power by $394.9 million and $362.9 million, respectively, at December 31, 2017. For the six months ended June 30, 2018, there were no adjustments in the ADIT liability related to the TCJA for Cleco or Cleco Power.

The impacts of the TCJA, 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 that any final adjustments to the provisional amounts will be recorded by the fourth quarter of 2018, which could have a material adverse effect on the results of operations of Cleco.

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Disclosures about Segments

6 Months Ended

Jun. 30, 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 following tables 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 following tables 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 JUNE 30,
2018 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	296,633		$	(2,420	)	$	—		$	294,213
Other operations	18,685			—			—			18,685
Electric customer credits	(13,637		)	—			—			(13,637		)
Affiliate revenue	220			17,273			(17,493		)	—
Operating revenue, net	$	301,901		$	14,853		$	(17,493	)	$	299,261
Depreciation and amortization	$	39,720		$	2,086		$	1		$	41,807
Interest charges	$	18,107		$	13,843		$	(41	)	$	31,909
Interest income	$	1,313		$	152		$	(38	)	$	1,427
Federal and state income tax expense (benefit)	$	13,710		$	(6,045	)	$	—		$	7,665
Net income (loss)	$	43,020		$	(17,182	)	$	1		$	25,839

2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	289,855		$	(2,420	)	$	—		$	287,435
Other operations	20,950			515			—			21,465
Electric customer credits	(239		)	—			—			(239		)
Affiliate revenue	221			13,631			(13,852		)	—
Operating revenue, net	$	310,787		$	11,726		$	(13,852	)	$	308,661
Depreciation and amortization	$	39,473		$	2,079		$	—		$	41,552
Interest charges	$	17,411		$	13,285		$	(75	)	$	30,621
Interest income	$	328		$	127		$	(74	)	$	381
Federal and state income tax expense (benefit)	$	23,063		$	(6,843	)	$	—		$	16,220
Net income (loss)	$	35,733		$	(10,289	)	$	—		$	25,444

SEGMENT INFORMATION FOR THE SIX MONTHS ENDED JUNE 30,
2018 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	561,264		$	(4,840	)	$	—		$	556,424
Other operations	40,880			1			—			40,881
Electric customer credits	(21,284		)	—			—			(21,284		)
Affiliate revenue	428			32,942			(33,370		)	—
Operating revenue, net	$	581,288		$	28,103		$	(33,370	)	$	576,021
Depreciation and amortization	$	80,109		$	4,205		$	—		$	84,314
Interest charges	$	35,763		$	27,392		$	(88	)	$	63,067
Interest income	$	1,953		$	342		$	(84	)	$	2,211
Federal and state income tax expense (benefit)	$	21,707		$	(11,180	)	$	1		$	10,528
Net income (loss)	$	69,024		$	(32,324	)	$	—		$	36,700
Additions to property, plant, and equipment	$	135,334		$	368		$	—		$	135,702
Equity investment in investees (1)	$	18,172		$	—		$	—		$	18,172
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,807,559		$	599,216		$	(21,164	)	$	6,385,611
(1) Balances as of June 30, 2018

2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	527,408		$	(5,917	)	$	—		$	521,491
Other operations	37,315			1,030						38,345
Electric customer credits	(674		)	—			—			(674		)
Affiliate revenue	440			28,365			(28,805		)	—
Operating revenue, net	$	564,489		$	23,478		$	(28,805	)	$	559,162
Depreciation and amortization	$	78,230		$	4,172		$	—		$	82,402
Interest charges	$	35,515		$	26,966		$	(142	)	$	62,339
Interest income	$	594		$	240		$	(141	)	$	693
Federal and state income tax expense (benefit)	$	32,918		$	(13,591	)	$	—		$	19,327
Net income (loss)	$	53,587		$	(21,851	)	$	—		$	31,736
Additions to property, plant, and equipment	$	127,297		$	1,396		$	—		$	128,693
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

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Regulation and Rates

6 Months Ended

Jun. 30, 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 ofJune 30, 2018,Cleco Power had $2.1 million accrued 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. Cleco Power responded to three sets of data requests from the LPSC for the 2017 monitoring report. On June 5, 2018, the LPSC filed its review of the 2017 FRP monitoring report which identified two exceptions; however, it concurred that no earnings-related refunds were due. Cleco Power filed a response to the review report on July 6, 2018, and anticipates filing a joint report for LPSC approval in the third quarter 2018. As of June 30, 2018, Cleco Power had $1.2 million accrued for the cost of service savings refund for the June 30, 2017 FRP monitoring report. Cleco Power expects to file its monitoring report for the 12 months ended June 30, 2018, on or before October 31, 2018, which will indicate that $5.9 million of earnings-related refunds and $1.2 million of cost of service savings refunds are due to be returned to eligible customers. These amounts were accrued at June 30, 2018.

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 in the third 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 was 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 June 30, 2018, Cleco Power had $4.4 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. On May 14, 2018, the settlement judge terminated the settlement proceedings. A hearing is scheduled for January 2019 with an initial decision from the ALJ expected in May 2019. 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. At June 30, 2018, Cleco Power had $14.7 million accrued for the estimated federal tax-related benefits from the TCJA. Cleco Power anticipates filing an application with the LPSC no later than August 31, 2018, for consideration of Cleco Power’s methodology for TCJA refunds and related items, including the allocation of such refunds among Cleco Power’s jurisdictional customers. Rates are anticipated to go into effect October 1, 2018. Cleco Power anticipates refunding the amount accrued for the change in the tax rate for the period January 2018 to September 2018 on customers’ September 2018 bills, based on July 2018 usage, pending LPSC review and approval. Cleco Power expects to address the regulatory liability for excess ADIT resulting from the enactment of the TCJA in Cleco Power’s application for its new FRP, which will be filed by June 30, 2019, with anticipated new rates being effective July 1, 2020.

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Variable Interest Entities

6 Months Ended

Jun. 30, 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 June 30, 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 JUNE 30, 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 JUNE 30, 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 JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
Operating revenue	$	1,057	$	532	$	1,920	$	1,605
Operating expenses	1,057		532		1,920		1,605
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.

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees

6 Months Ended

Jun. 30, 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, BCI, 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 and May 2016, the plaintiffs filed their Third Consolidated Amended Verified Derivative Petition for Damages and Preliminary and Permanent Injunction and their Fourth Verified Consolidated Amended Class Action Petition, respectively. The fourth 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 in September 2016, and 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. In January 2018, Cleco filed a writ with the Louisiana Supreme Court seeking review of the Third Circuit Court of Appeal’s decision. The writ was denied in March 2018. 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 briefing on Cleco Power’s motion is now complete, but the district court has not ruled on the motion or set a hearing date.

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. 18-cv-153, U.S. District Court for the Eastern District of Texas. The allegations are essentially identical to those in the BoninCase. On April 13, 2018, Cleco Power filed a motion to dismiss on the same grounds that previously were successful in the Bonin Case. The briefing on Cleco Power’s motion is complete, but the district court has not ruled on the motion or set a hearing date. On July 20, 2018, the district court entered an order consolidating the Addison Case with the Bonin Case. 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. Cleco Power has responded to two sets of data requests. Periods subsequent to December 31, 2017, are also subject to audit. 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. On May 22, 2018, Cleco Power received notice of an EAC audit from the LPSC for the period of January 1, 2016 to December 31, 2017. The total amount of environmental expense included in the audit is $30.7 million. Cleco Power has responded to one set of data requests. Periods subsequent to December 31, 2017, are also subject to audit. 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 environmental 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.

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

Generally, Cleco Power records wholesale transmission revenue through Attachment O of the MISO tariff and certain grandfathered agreements. These rates are subject to periodic audits by FERC. 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 of January 1, 2014, to the present. Management has met with the auditors to discuss the progress of the audit. On July 31, 2018, Cleco Power received its first set of data requests related to this audit. 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 June 30, 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 June 30, 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 standby letters of credit, in order to facilitate their activities and the activities of Cleco Holdings’ subsidiaries and equity investees (affiliates). Cleco Holdings and Cleco Power have also agreed to contractual terms that require the Registrants to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees.

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

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

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

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

Cleco Holdings provided indemnifications to Cleco Power as a result of the transfer of Coughlin to Cleco Power in March 2014. Cleco Power also provided indemnifications to Cleco Holdings and Evangeline as a result of the transfer of Coughlin to Cleco Power. The maximum amount of the potential payment to Cleco Power, Cleco Holdings, and Evangeline for their respective indemnifications is $40.0 million, except for indemnifications relating to the fundamental organizational structure of each respective entity, of which the maximum amount is $400.0 million. Management does not expect to be required to make any payments under these indemnifications.

As part of the Amended Lignite Mining Agreement, Cleco Power and SWEPCO, joint owners of 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 June 30, 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 is being recognized over a ten-year period, which is projected to be completed by the end of 2018. 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. From September 2017 until April 2, 2018, Cleco Power had an operating lease that automatically renewed on a month-to-month basis for use of the 42 barges. On April 2, 2018, Cleco Power loaned Savage Inland Marine $16.8 million to purchase the barges. Also on April 2, 2018, 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.

Under the 2018 agreement, the barge lease rate contains both a fixed and variable component of which the latter will be adjusted every third anniversary of the new agreement for estimated executory costs. If the barges are idle, the lessor is required to attempt to sublease the barges to third parties with the revenue reducing Cleco Power’s lease payment. For the three and six months ended June 30, 2018, Cleco Power paid approximately $0.7 million in lease payments and received $0.1 million of revenue from subleases.

This agreement contains a provision for early termination upon the occurrence of any one of four cancellation events.

The following is an analysis of the leased property under Cleco Power’s capital lease:

(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Barges	$	16,800	$	—
Less: accumulated amortization	280		—
Net capital lease	$	16,520	$	—

The following is a schedule by years of future minimum lease payments under the capital lease together with the present value of the net minimum lease payments as of June 30, 2018:

	(THOUSANDS)
Six months ending Dec. 31, 2018	$	1,306
Years ending Dec. 31,
2019	2,611
2020	2,611
2021	2,611
2022	2,611
2023	2,611
Thereafter	23,654
Total minimum lease payments	38,015
Less: executory costs	6,021
Net minimum lease payments	31,994
Less: amount representing interest	15,318
Present value of net minimum lease payments	$	16,676
Current liabilities	$	529
Non-current liabilities	$	16,147

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 long-term issuer credit rating on review for downgrade and affirmed Cleco Power at A3 (stable). Also on February 7, 2018, taking into consideration the pending NRG South Central acquisition, S&P affirmed Cleco Holdings’ and Cleco Power’s corporate 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. On May 11, 2018, taking into consideration the pending NRG South Central acquisition, Fitch assigned a first-time long-term issuer default rating of BBB- at Cleco Holdings and BBB at Cleco Power. If Cleco Holdings’ or Cleco Power’s credit ratings were to be downgraded Cleco Holdings or Cleco Power could be required to pay additional fees and incur higher interest rates for borrowings under their respective credit facilities. On July 31, 2018, Cleco amended its $300.0 million bank term loan agreement and its $100.0 million revolving credit facility agreement to release any and all collateral from all of its debt obligations under those agreements. As a result of the release of collateral, Cleco Holdings expects Moody’s and Fitch to update Cleco Holdings’ senior debt rating.

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 higher LMPs. 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.

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Affiliate Transactions

6 Months Ended

Jun. 30, 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 JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	212	$	129	$	743	$	113
Support Group	486		10,572		608		8,582
Other (1)	—		—		4		2
Total	$	698	$	10,701	$	1,355	$	8,697
(1) Represents Attala and Perryville.

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Intangible Assets

6 Months Ended

Jun. 30, 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 and six months ended June 30, 2018, Cleco Katrina/Rita recognized amortization expense of $5.5 million and $10.0 million, respectively, based on actual collections. During the three and six months ended June 30, 2017, Cleco Katrina/Rita recognized amortization expense of $4.7 million and $8.2 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 and six months ended June 30, 2018, Cleco recognized amortization expense of less than $0.1 million and $0.1 million, respectively, on the trade name intangible asset. During the three and six months ended June 30, 2017, Cleco recognized amortization expense of less than $0.1 million and $0.1 million, respectively, 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 and six months ended June 30, 2018, Cleco recognized a reduction of revenue of $2.4 million, and $4.8 million, respectively, on the intangible assets for the power supply agreements. During the three and six months ended June 30, 2017, Cleco recognized a reduction of revenue of $2.4 million and $6.0 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 June 30, 2018, and December 31, 2017:

Cleco
(THOUSANDS)	AT JUNE 30, 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	(60,909		)	(45,948		)
Net intangible assets subject to amortization	$	99,889		$	114,850

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018			AT DEC. 31, 2017
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	177,537		$	177,537
Accumulated amortization	(145,830		)	(135,836		)
Net intangible assets subject to amortization	$	31,707		$	41,701

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Accumulated Other Comprehensive Loss

6 Months Ended

Jun. 30, 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 JUNE 30, 2018			FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(2,878	)	$	(2,921	)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	247			290
Net current-period other comprehensive income	247			290
Balances, June 30, 2018	$	(2,631	)	$	(2,631	)

	FOR THE THREE MONTHS ENDED JUNE 30, 2017			FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(691	)	$	1,500
Other comprehensive income (loss) before reclassifications
Postretirement benefits adjustment during the period	—			(2,065		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss (gain)	60			(66		)
Net current-period other comprehensive income (loss)	60			(2,131		)
Balances, June 30, 2017	$	(631	)	$	(631	)

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2018									FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI			POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(8,144	)	$	(5,242	)	$	(13,386	)	$	(8,377	)	$	(5,306	)	$	(13,683	)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	267			—			267			500			—			500
Reclassification of net loss to interest charges	—			64			64			—			128			128
Net current-period other comprehensive income	267			64			331			500			128			628
Balances, June 30, 2018	$	(7,877	)	$	(5,178	)	$	(13,055	)	$	(7,877	)	$	(5,178	)	$	(13,055	)

	FOR THE THREE MONTHS ENDED JUNE 30, 2017									FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI			POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(8,325	)	$	(5,464	)	$	(13,789	)	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive income (loss) before reclassifications
Postretirement benefit adjustments during the period	—			—			—			(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	193			—			193			357			—			357
Reclassification of net loss to interest charges	—			53			53			—			106			106
Net current-period other comprehensive income (loss)	193			53			246			(227		)	106			(121		)
Balances, June 30, 2017	$	(8,132	)	$	(5,411	)	$	(13,543	)	$	(8,132	)	$	(5,411	)	$	(13,543	)

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Plan of Acquisition Plan of Acquisition

6 Months Ended

Jun. 30, 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 by FERC, the LPSC, the Public Utility Commission of Texas, and final approval from the Federal Communications Commission (FCC). On February 27, 2018, Cleco filed a joint application seeking approval of the transaction with FERC. 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 the Public Utility Commission of Texas seeking approval of the transaction. On June 19, 2018, the Committee on Foreign Investment in the United States approved and cleared Cleco’s application for the transaction to proceed. On July 10, 2018, the FCC’s consent to transfer two of three licenses to Cleco Cajun became final. The FCC’s consent to transfer the third license is expected to become final on August 7, 2018. Cleco is in the process of responding to data requests from the LPSC staff for the LPSC application.

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.

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Summary of Significant Accounting Policies (Policies)

6 Months Ended

Jun. 30, 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 SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Transfer of cash from restricted accounts, net	$	6,003		$	—
Net cash used in investing activities	$	(119,066	)	$	(125,069	)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	$	(12,565	)	$	(18,568	)
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	$	10,512		$	51,003

Cleco Power
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Transfer of cash from restricted accounts, net	$	6,003		$	—
Net cash used in investing activities	$	(117,881	)	$	(123,884	)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	$	(18,013	)	$	(24,016	)
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	$	3,469		$	43,939

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 JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	29,256		$	26,235
Total operating expenses	$	238,412		$	235,391
Operating income	$	70,249		$	73,270
Other expense	$	(260	)	$	(3,281	)

Cleco
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	61,244		$	55,561		*
Total operating expenses	$	450,114		$	444,429
Operating income	$	109,048		$	114,733
Other expense	$	(534	)	$	(6,219	)
* Also reflects less than $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 JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	29,782		$	27,649
Total operating expenses	$	236,253		$	234,120
Operating income	$	74,534		$	76,667
Other expense	$	(260	)	$	(2,393	)

Cleco Power
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	61,770		$	57,913
Total operating expenses	$	445,254		$	441,397
Operating income	$	119,235		$	123,092
Other expense	$	(534	)	$	(4,391	)

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.

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.

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 the plan sponsor and Support Group is the plan administrator.

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 following tables 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.

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Summary of Significant Accounting Policies (Tables)

6 Months Ended

Jun. 30, 2018

Restricted Cash and Cash Equivalents Items [Line Items]

Restricted Cash and Cash Equivalents

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

Cleco
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current
Cleco Katrina/Rita’s storm recovery bonds	$	8,144	$	8,597
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	601		3,284
Total current	9,945		13,081
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	14,934		14,456
Cleco Power’s charitable contributions	2,933		3,575
Cleco Power’s rate credit escrow	1,192		2,029
Total non-current	19,080		20,081
Total restricted cash and cash equivalents	$	29,025	$	33,162

CLECO POWER

Restricted Cash and Cash Equivalents Items [Line Items]

Restricted Cash and Cash Equivalents

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current
Cleco Katrina/Rita’s storm recovery bonds	$	8,144	$	8,597
Charitable contributions	1,200		1,200
Rate credit escrow	601		3,284
Total current	9,945		13,081
Non-current
Future storm restoration costs	14,934		14,456
Charitable contributions	2,933		3,575
Rate credit escrow	1,192		2,029
Total non-current	19,059		20,060
Total restricted cash and cash equivalents	$	29,004	$	33,141

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Revenue Recognition (Tables)

6 Months Ended

Jun. 30, 2018

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

Operating revenue, net for the three and six months ended June 30, 2018, was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	CLECO POWER			OTHER				ELIMINATIONS			TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	107,805		$	—			$	—		$	107,805
Commercial (1)	71,865			—				—			71,865
Industrial (1)	40,679			—				—			40,679
Other retail (1)	3,793			—				—			3,793
Surcharge	6,193			—				—			6,193
Total retail revenue	$	230,335		$	—			$	—		$	230,335
Wholesale, net (1)	54,662			(2,420		)	(2)	—			52,242
Transmission	11,943			—				—			11,943
Other (3)	(6,895		)	—				—			(6,895		)
Total revenue from contracts with customers	$	290,045		$	(2,420	)		$	—		$	287,625
Revenue unrelated to contracts with customers
Affiliate	$	220		$	17,273			$	(17,493	)	$	—
Other	11,636			—				—			11,636
Total revenue unrelated to contracts with customers	11,856			17,273				(17,493		)	11,636
Operating revenue, net	$	301,901		$	14,853			$	(17,493	)	$	299,261

⁽¹⁾ Includes fuel recovery revenue.

⁽²⁾ Amortization of intangible assets related to wholesale power supply agreements.

⁽³⁾ Other revenue from contracts with customers includes $13.6 million of electric customer credits, partially offset by $4.1 million of other miscellaneous fee revenue, and $2.6 million of Teche Unit 3 SSR revenue, net of $0.3 million of reserves for capital expenditures.

	FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	CLECO POWER			OTHER				ELIMINATIONS			TOTAL
Revenue from contracts with customers
Retail revenue
Residential (1)	$	199,195		$	—			$	—		$	199,195
Commercial (1)	138,560			—				—			138,560
Industrial (1)	78,065			—				—			78,065
Other retail (1)	7,594			—				—			7,594
Surcharge	11,431			—				—			11,431
Total retail revenue	$	434,845		$	—			$	—		$	434,845
Wholesale, net (1)	101,631			(4,840		)	(2)	—			96,791
Transmission	26,448			—				—			26,448
Other (3)	(6,852		)	1				—			(6,851		)
Total revenue from contracts with customers	$	556,072		$	(4,839	)		$	—		$	551,233
Revenue unrelated to contracts with customers
Affiliate	$	428		$	32,942			$	(33,370	)	$	—
Other	24,788			—				—			24,788
Total revenue unrelated to contracts with customers	25,216			32,942				(33,370		)	24,788
Operating revenue, net	$	581,288		$	28,103			$	(33,370	)	$	576,021

⁽¹⁾ Includes fuel recovery revenue.

⁽²⁾ Amortization of intangible assets related to wholesale power supply agreements.

⁽³⁾ Other revenue from contracts with customers includes $21.3 million of electric customer credits, partially offset by $8.6 million of other miscellaneous fee revenue, and $5.8 million of Teche Unit 3 SSR revenue, net of $2.2 million of reserves for capital expenditures.

Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction

For 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 June 30, 2018, and (2) when Cleco expects to recognize this revenue:

REMAINING PERFORMANCE OBLIGATIONS	(THOUSANDS)
Six months ending Dec. 31, 2018	$	24,213
Years ending Dec. 31,
2019	23,874
2020	7,068
2021	7,068
2022	6,468
Thereafter	10,210
Total remaining performance obligations	$	78,901

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Recent Authoritative Guidance (Tables)

6 Months Ended

Jun. 30, 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 SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Transfer of cash from restricted accounts, net	$	6,003		$	—
Net cash used in investing activities	$	(119,066	)	$	(125,069	)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	$	(12,565	)	$	(18,568	)
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	$	10,512		$	51,003

Cleco Power
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Transfer of cash from restricted accounts, net	$	6,003		$	—
Net cash used in investing activities	$	(117,881	)	$	(123,884	)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	$	(18,013	)	$	(24,016	)
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	$	3,469		$	43,939

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 JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	29,256		$	26,235
Total operating expenses	$	238,412		$	235,391
Operating income	$	70,249		$	73,270
Other expense	$	(260	)	$	(3,281	)

Cleco
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	61,244		$	55,561		*
Total operating expenses	$	450,114		$	444,429
Operating income	$	109,048		$	114,733
Other expense	$	(534	)	$	(6,219	)
* Also reflects less than $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 JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	29,782		$	27,649
Total operating expenses	$	236,253		$	234,120
Operating income	$	74,534		$	76,667
Other expense	$	(260	)	$	(2,393	)

Cleco Power
	FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	AS REPORTED			AS ADJUSTED
Other operations expenses	$	61,770		$	57,913
Total operating expenses	$	445,254		$	441,397
Operating income	$	119,235		$	123,092
Other expense	$	(534	)	$	(4,391	)

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Regulatory Assets and Liabilities (Tables)

6 Months Ended

Jun. 30, 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 JUNE 30, 2018		AT DEC. 31, 2017
Total Cleco Power regulatory assets, net	$	161,337	$	146,774
Cleco Merger adjustments (1)
Fair value of long-term debt	142,922		147,145
Postretirement costs	20,381		21,375
Financing costs	8,450		8,623
Debt issuance costs	6,459		6,665
Total Cleco regulatory assets, net	$	339,549	$	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 JUNE 30, 2018			AT DEC. 31, 2017
Regulatory liabilities - deferred taxes, net	$	(136,447	)	$	(140,426	)
Mining costs	2,549			3,823
Interest costs	4,340			4,499
AROs	2,824			2,762
Postretirement costs	136,644			142,764
Tree trimming costs	8,015			7,193
Training costs	6,474			6,552
Surcredits, net	289			2,173
AMI deferred revenue requirement	3,954			4,227
Emergency declarations	3,781			4,131
Production operations and maintenance expenses	5,827			8,625
AFUDC equity gross-up	71,295			71,205
Acadia Unit 1 acquisition costs	2,283			2,336
Financing costs	8,108			8,293
MISO integration costs	—			468
Coughlin transaction costs	953			968
Corporate franchise tax, net	1,500			153
MATS costs	—			2,564
Non-service cost of postretirement benefits	2,136			—
Other	26			484
Total regulatory assets	260,998			273,220
Accumulated deferred fuel	36,786			13,980
Total regulatory assets, net	$	161,337		$	146,774

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Fair Value Accounting (Tables)

6 Months Ended

Jun. 30, 2018

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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 JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,903,190	$	2,865,196	$	2,866,955	$	2,921,325

* The carrying value of long-term debt does not include deferred issuance costs of $11.1 million and $11.6 million at June 30, 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 JUNE 30, 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	$	141,290	$	—	$	141,290	$	—	$	144,302	$	—	$	144,302	$	—
FTRs	26,077		—		—		26,077		7,396		—		—		7,396
Total assets	$	167,367	$	—	$	141,290	$	26,077	$	151,698	$	—	$	144,302	$	7,396
Liability description
FTRs	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352
Total liabilities	$	944	$	—	$	—	$	944	$	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 JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018			2017
Beginning balance	$	4,283		$	4,418		$	7,044		$	7,683
Unrealized gains (losses)*	2,420			(2,460		)	2,420			(2,460		)
Purchases	25,112			22,843			25,483			23,118
Settlements	(6,682		)	(6,858		)	(9,814		)	(10,398		)
Ending balance	$	25,133		$	17,943		$	25,133		$	17,943
* 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 June 30, 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 June 30, 2018	$	26,077	$	944	RTO auction pricing	FTR price - per MWh	$	(3.84	)	$	7.42
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, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [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 June 30, 2018, and December 31, 2017:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT JUNE 30, 2018		AT DEC. 31, 2017
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	26,077	$	7,396
Current	Other current liabilities	944		352
Commodity-related contracts, net		$	25,133	$	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 six months ended June 30, 2018, and 2017:

	AMOUNT OF GAIN(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	DERIVATIVES LINE ITEM	2018			2017			2018			2017
Commodity contracts
FTRs(1)	Electric operations	$	17,841		$	11,947		$	35,991		$	21,110
FTRs(1)	Power purchased for utility customers	(7,027		)	(6,327		)	(12,693		)	(10,992		)
Total		$	10,814		$	5,620		$	23,298		$	10,118

⁽¹⁾ For the three and six months ended June 30, 2018, unrealized gains associated with FTRs of $2.4 million were reported through Accumulated deferred fuel on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. For the three and six months ended June 30, 2017, unrealized losses associated with FTRs of $2.5 million were reported through Accumulated deferred fuel on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets.

CLECO POWER

Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]

Fair Value By Balance Sheet Grouping

Cleco Power
	AT JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,410,267	$	1,518,752	$	1,369,810	$	1,535,234

* The carrying value of long-term debt does not include deferred issuance costs of $8.8 million and $9.1 million at June 30, 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 JUNE 30, 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	$	96,568	$	—	$	96,568	$	—	$	95,681	$	—	$	95,681	$	—
FTRs	26,077		—		—		26,077		7,396		—		—		7,396
Total assets	$	122,645	$	—	$	96,568	$	26,077	$	103,077	$	—	$	95,681	$	7,396
Liability description
FTRs	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352
Total liabilities	$	944	$	—	$	—	$	944	$	352	$	—	$	—	$	352

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Pension Plan and Employee Benefits (Tables)

6 Months Ended

Jun. 30, 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 and six months ended June 30, 2018, and 2017 were as follows:

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED JUNE 30,						FOR THE THREE MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018		2017
Components of periodic benefit costs
Service cost	$	2,361		$	2,295		$	338	$	385
Interest cost	5,472			5,467			357		402
Expected return on plan assets	(5,938		)	(5,895		)	—		—
Amortizations
Prior period service credit	(18		)	(18		)	—		—
Net loss (gain)	2,960			2,591			5		(2		)
Net periodic benefit cost	$	4,837		$	4,440		$	700	$	785

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE SIX MONTHS ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018		2017
Components of periodic benefit costs
Service cost	$	4,753		$	4,520		$	675	$	770
Interest cost	10,654			10,824			715		805
Expected return on plan assets	(11,875		)	(12,032		)	—		—
Amortizations
Prior period service credit	(36		)	(36		)	—		—
Net loss (gain)	5,921			5,004			10		(5		)
Net periodic benefit cost	$	9,417		$	8,280		$	1,400	$	1,570

401(k) Plan expense

Cleco’s 401(k) Plan expense for the three and six monthsended June 30, 2018, and 2017 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
401(k) Plan expense	$	1,229	$	1,204	$	3,292	$	2,872

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 June 30, 2018, and December 31, 2017, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	4,061	$	4,061
Non-current	$	38,270	$	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 and six months ended June 30, 2018, and 2017 were as follows:

	FOR THE THREE MONTHS  ENDED JUNE 30,						FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018			2017			2018			2017
Components of periodic benefit costs
Service cost	$	166		$	102		$	271		$	247
Interest cost	1,004			820			1,764			1,620
Amortizations
Prior period service credit	(47		)	(29		)	(81		)	(68		)
Net loss	647			624			1,232			1,025
Net periodic benefit cost	1,770			1,517			3,186			2,824
Special/contractual termination benefits	—			—			—			315
Total benefit cost	$	1,770		$	1,517		$	3,186		$	3,139

Schedule of current and non-current portions

The current and non-current portions of the SERP liability for Cleco and Cleco Power at June 30, 2018, and December 31, 2017, were as follows:

Cleco
(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Current	$	4,471	$	4,471
Non-current	$	79,487	$	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 and six months ended June 30, 2018, and 2017 was as follows:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
401(k) Plan expense	$	209	$	198	$	611	$	477

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 JUNE 30, 2018		AT DEC. 31, 2017
Current	$	3,525	$	3,525
Non-current	$	33,302	$	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 JUNE 30, 2018		AT DEC. 31, 2017
Current	$	929	$	929
Non-current	$	12,934	$	16,589

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Income Taxes (Tables)

6 Months Ended

Jun. 30, 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 and six months ended June 30, 2018, and 2017:

Cleco
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2018		2017		2018		2017
Effective tax rate	22.9	%	38.9	%	22.3	%	37.8	%

CLECO POWER

Effective Income Tax Rate [Line Items]

Effective income tax rates

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS ENDED JUNE 30,
	2018		2017		2018		2017
Effective tax rate	24.2	%	39.2	%	23.9	%	38.1	%

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Disclosures about Segments (Tables)

6 Months Ended

Jun. 30, 2018

Segment Reporting [Abstract]

Segment Information

The financial results in the following tables 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 JUNE 30,
2018 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	296,633		$	(2,420	)	$	—		$	294,213
Other operations	18,685			—			—			18,685
Electric customer credits	(13,637		)	—			—			(13,637		)
Affiliate revenue	220			17,273			(17,493		)	—
Operating revenue, net	$	301,901		$	14,853		$	(17,493	)	$	299,261
Depreciation and amortization	$	39,720		$	2,086		$	1		$	41,807
Interest charges	$	18,107		$	13,843		$	(41	)	$	31,909
Interest income	$	1,313		$	152		$	(38	)	$	1,427
Federal and state income tax expense (benefit)	$	13,710		$	(6,045	)	$	—		$	7,665
Net income (loss)	$	43,020		$	(17,182	)	$	1		$	25,839

2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	289,855		$	(2,420	)	$	—		$	287,435
Other operations	20,950			515			—			21,465
Electric customer credits	(239		)	—			—			(239		)
Affiliate revenue	221			13,631			(13,852		)	—
Operating revenue, net	$	310,787		$	11,726		$	(13,852	)	$	308,661
Depreciation and amortization	$	39,473		$	2,079		$	—		$	41,552
Interest charges	$	17,411		$	13,285		$	(75	)	$	30,621
Interest income	$	328		$	127		$	(74	)	$	381
Federal and state income tax expense (benefit)	$	23,063		$	(6,843	)	$	—		$	16,220
Net income (loss)	$	35,733		$	(10,289	)	$	—		$	25,444

SEGMENT INFORMATION FOR THE SIX MONTHS ENDED JUNE 30,
2018 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	561,264		$	(4,840	)	$	—		$	556,424
Other operations	40,880			1			—			40,881
Electric customer credits	(21,284		)	—			—			(21,284		)
Affiliate revenue	428			32,942			(33,370		)	—
Operating revenue, net	$	581,288		$	28,103		$	(33,370	)	$	576,021
Depreciation and amortization	$	80,109		$	4,205		$	—		$	84,314
Interest charges	$	35,763		$	27,392		$	(88	)	$	63,067
Interest income	$	1,953		$	342		$	(84	)	$	2,211
Federal and state income tax expense (benefit)	$	21,707		$	(11,180	)	$	1		$	10,528
Net income (loss)	$	69,024		$	(32,324	)	$	—		$	36,700
Additions to property, plant, and equipment	$	135,334		$	368		$	—		$	135,702
Equity investment in investees (1)	$	18,172		$	—		$	—		$	18,172
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,807,559		$	599,216		$	(21,164	)	$	6,385,611
(1) Balances as of June 30, 2018

2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	527,408		$	(5,917	)	$	—		$	521,491
Other operations	37,315			1,030						38,345
Electric customer credits	(674		)	—			—			(674		)
Affiliate revenue	440			28,365			(28,805		)	—
Operating revenue, net	$	564,489		$	23,478		$	(28,805	)	$	559,162
Depreciation and amortization	$	78,230		$	4,172		$	—		$	82,402
Interest charges	$	35,515		$	26,966		$	(142	)	$	62,339
Interest income	$	594		$	240		$	(141	)	$	693
Federal and state income tax expense (benefit)	$	32,918		$	(13,591	)	$	—		$	19,327
Net income (loss)	$	53,587		$	(21,851	)	$	—		$	31,736
Additions to property, plant, and equipment	$	127,297		$	1,396		$	—		$	128,693
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

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Variable Interest Entities (Tables) - CLECO POWER

6 Months Ended

Jun. 30, 2018

Variable Interest Entity [Line Items]

Equity Method Investments

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

INCEPTION TO DATE (THOUSANDS)	AT JUNE 30, 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 contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED JUNE 30,				FOR THE SIX MONTHS  ENDED JUNE 30,
(THOUSANDS)	2018		2017		2018		2017
Operating revenue	$	1,057	$	532	$	1,920	$	1,605
Operating expenses	1,057		532		1,920		1,605
Income before taxes	$	—	$	—	$	—	$	—

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 JUNE 30, 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

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees (Tables) - Cleco Power

6 Months Ended

Jun. 30, 2018

Loss Contingencies [Line Items]

Schedule of Capital Leased Assets

The following is an analysis of the leased property under Cleco Power’s capital lease:

(THOUSANDS)	AT JUNE 30, 2018		AT DEC. 31, 2017
Barges	$	16,800	$	—
Less: accumulated amortization	280		—
Net capital lease	$	16,520	$	—

Schedule of Future Minimum Lease Payments for Capital Leases

The following is a schedule by years of future minimum lease payments under the capital lease together with the present value of the net minimum lease payments as of June 30, 2018:

	(THOUSANDS)
Six months ending Dec. 31, 2018	$	1,306
Years ending Dec. 31,
2019	2,611
2020	2,611
2021	2,611
2022	2,611
2023	2,611
Thereafter	23,654
Total minimum lease payments	38,015
Less: executory costs	6,021
Net minimum lease payments	31,994
Less: amount representing interest	15,318
Present value of net minimum lease payments	$	16,676
Current liabilities	$	529
Non-current liabilities	$	16,147

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Affiliate Transactions (Tables)

6 Months Ended

Jun. 30, 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 JUNE 30, 2018				AT DEC. 31, 2017
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	212	$	129	$	743	$	113
Support Group	486		10,572		608		8,582
Other (1)	—		—		4		2
Total	$	698	$	10,701	$	1,355	$	8,697
(1) Represents Attala and Perryville.

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Intangible Assets (Tables)

6 Months Ended

Jun. 30, 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 June 30, 2018, and December 31, 2017:

Cleco
(THOUSANDS)	AT JUNE 30, 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	(60,909		)	(45,948		)
Net intangible assets subject to amortization	$	99,889		$	114,850

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018			AT DEC. 31, 2017
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	177,537		$	177,537
Accumulated amortization	(145,830		)	(135,836		)
Net intangible assets subject to amortization	$	31,707		$	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 June 30, 2018, and December 31, 2017:

Cleco
(THOUSANDS)	AT JUNE 30, 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	(60,909		)	(45,948		)
Net intangible assets subject to amortization	$	99,889		$	114,850

Cleco Power
(THOUSANDS)	AT JUNE 30, 2018			AT DEC. 31, 2017
Cleco Katrina/Rita right to bill and collect storm recovery charges	$	177,537		$	177,537
Accumulated amortization	(145,830		)	(135,836		)
Net intangible assets subject to amortization	$	31,707		$	41,701

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Accumulated Other Comprehensive Loss (Tables)

6 Months Ended

Jun. 30, 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 JUNE 30, 2018			FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(2,878	)	$	(2,921	)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	247			290
Net current-period other comprehensive income	247			290
Balances, June 30, 2018	$	(2,631	)	$	(2,631	)

	FOR THE THREE MONTHS ENDED JUNE 30, 2017			FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS
Balances, beginning of period	$	(691	)	$	1,500
Other comprehensive income (loss) before reclassifications
Postretirement benefits adjustment during the period	—			(2,065		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss (gain)	60			(66		)
Net current-period other comprehensive income (loss)	60			(2,131		)
Balances, June 30, 2017	$	(631	)	$	(631	)

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2018									FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI			POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(8,144	)	$	(5,242	)	$	(13,386	)	$	(8,377	)	$	(5,306	)	$	(13,683	)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	267			—			267			500			—			500
Reclassification of net loss to interest charges	—			64			64			—			128			128
Net current-period other comprehensive income	267			64			331			500			128			628
Balances, June 30, 2018	$	(7,877	)	$	(5,178	)	$	(13,055	)	$	(7,877	)	$	(5,178	)	$	(13,055	)

CLECO POWER

Accumulated Other Comprehensive Loss [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss)

Cleco Power
	FOR THE THREE MONTHS ENDED JUNE 30, 2018									FOR THE SIX MONTHS ENDED JUNE 30, 2018
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI			POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(8,144	)	$	(5,242	)	$	(13,386	)	$	(8,377	)	$	(5,306	)	$	(13,683	)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	267			—			267			500			—			500
Reclassification of net loss to interest charges	—			64			64			—			128			128
Net current-period other comprehensive income	267			64			331			500			128			628
Balances, June 30, 2018	$	(7,877	)	$	(5,178	)	$	(13,055	)	$	(7,877	)	$	(5,178	)	$	(13,055	)

	FOR THE THREE MONTHS ENDED JUNE 30, 2017									FOR THE SIX MONTHS ENDED JUNE 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI			POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(8,325	)	$	(5,464	)	$	(13,789	)	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive income (loss) before reclassifications
Postretirement benefit adjustments during the period	—			—			—			(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	193			—			193			357			—			357
Reclassification of net loss to interest charges	—			53			53			—			106			106
Net current-period other comprehensive income (loss)	193			53			246			(227		)	106			(121		)
Balances, June 30, 2017	$	(8,132	)	$	(5,411	)	$	(13,543	)	$	(8,132	)	$	(5,411	)	$	(13,543	)

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Summary of Significant Accounting Policies - Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018	Dec. 31, 2017
Restricted Cash and Cash Equivalents Items [Line Items]
Current	$ 9,945	$ 13,081
Non-current	19,080	20,081
Total restricted cash and cash equivalents	29,025	33,162
Cleco Katrina/Rita’s storm recovery bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Current	8,144	8,597
Charitable contributions
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,200	1,200
Non-current	2,933	3,575
Rate credit escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Current	601	3,284
Non-current	1,192	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	14,934	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
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	10,600
CLECO POWER
Restricted Cash and Cash Equivalents Items [Line Items]
Current	9,945	13,081
Non-current	19,059	20,060
Total restricted cash and cash equivalents	29,004	33,141
CLECO POWER | Cleco Katrina/Rita’s storm recovery bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Current	8,144	8,597
CLECO POWER | Charitable contributions
Restricted Cash and Cash Equivalents Items [Line Items]
Current	1,200	1,200
Non-current	2,933	3,575
CLECO POWER | Rate credit escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Current	601	3,284
Non-current	1,192	2,029
CLECO POWER | Future storm restoration costs
Restricted Cash and Cash Equivalents Items [Line Items]
Non-current	$ 14,934	$ 14,456

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Summary of Significant Accounting Policies - Risk Management (Details) - derivative	6 Months Ended
	Jun. 30, 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

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Revenue Recognition - Narrative (Details)	6 Months Ended
	Jun. 30, 2018
Revenue from Contract with Customer [Abstract]
Payment terms	20 days

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Revenue Recognition - Disaggregation of Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 287,625		$ 551,233
Revenue unrelated to contracts with customers
Affiliate revenue	0	$ 0	0	$ 0
Other	11,636		24,788
Total revenue unrelated to contracts with customers	11,636		24,788
Operating revenue, net	299,261	308,661	576,021	559,162
Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	230,335		434,845
Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	107,805		199,195
Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	71,865		138,560
Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	40,679		78,065
Other retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3,793		7,594
Surcharge
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6,193		11,431
Wholesale, net
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	52,242		96,791
Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	11,943		26,448
Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	(6,895)		(6,851)
CLECO POWER | Other
Revenue unrelated to contracts with customers
Other fee revenue	4,100		8,600
Reserve for capital expenditures	300		2,200
Operating Segments | CLECO POWER
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	290,045		556,072
Revenue unrelated to contracts with customers
Affiliate revenue	220	221	428	440
Other	11,636		24,788
Total revenue unrelated to contracts with customers	11,856		25,216
Operating revenue, net	301,901	310,787	581,288	564,489
Operating Segments | CLECO POWER | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	230,335		434,845
Operating Segments | CLECO POWER | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	107,805		199,195
Operating Segments | CLECO POWER | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	71,865		138,560
Operating Segments | CLECO POWER | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	40,679		78,065
Operating Segments | CLECO POWER | Other retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	3,793		7,594
Operating Segments | CLECO POWER | Surcharge
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	6,193		11,431
Operating Segments | CLECO POWER | Wholesale, net
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	54,662		101,631
Operating Segments | CLECO POWER | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	11,943		26,448
Operating Segments | CLECO POWER | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	(6,895)		(6,852)
Operating Segments | OTHER
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	(2,420)		(4,839)
Revenue unrelated to contracts with customers
Affiliate revenue	17,273	13,631	32,942	28,365
Other	0		0
Total revenue unrelated to contracts with customers	17,273		32,942
Operating revenue, net	14,853	11,726	28,103	23,478
Operating Segments | OTHER | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
Operating Segments | OTHER | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
Operating Segments | OTHER | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
Operating Segments | OTHER | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
Operating Segments | OTHER | Other retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
Operating Segments | OTHER | Surcharge
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
Operating Segments | OTHER | Wholesale, net
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	(2,420)		(4,840)
Operating Segments | OTHER | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
Operating Segments | OTHER | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		1
ELIMINATIONS
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
Revenue unrelated to contracts with customers
Affiliate revenue	(17,493)	(13,852)	(33,370)	(28,805)
Other	0		0
Total revenue unrelated to contracts with customers	(17,493)		(33,370)
Operating revenue, net	(17,493)	(13,852)	(33,370)	(28,805)
ELIMINATIONS | Total retail revenue
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
ELIMINATIONS | Residential
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
ELIMINATIONS | Commercial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
ELIMINATIONS | Industrial
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
ELIMINATIONS | Other retail
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
ELIMINATIONS | Surcharge
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
ELIMINATIONS | Wholesale, net
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
ELIMINATIONS | Transmission
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
ELIMINATIONS | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	0		0
CLECO POWER
Revenue unrelated to contracts with customers
Affiliate revenue	220	221	428	440
Operating revenue, net	301,901	$ 310,787	581,288	$ 564,489
CLECO POWER | Electric Customer Credits
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	13,600		21,300
SSR | CLECO POWER | Other
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 2,600		$ 5,800

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Revenue Recognition - Remaining Performance Obligations (Details) $ in Thousands	6 Months Ended
	Jun. 30, 2018 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2018-07-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 24,213
Revenue, remaining performance obligation, expected timing of satisfaction, period	6 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	$ 23,874
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	$ 78,901
Revenue, remaining performance obligation, expected timing of satisfaction, period

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Recent Authoritative Guidance - ASU 2016-18 (Details) - USD ($) $ in Thousands	6 Months Ended
	Jun. 30, 2018		Jun. 30, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net cash used in investing activities	$ (142,245)		$ (125,069)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	(6,865)		(18,568)
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	145,337	[2]	51,003
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			(125,069)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents			(18,568)
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			51,003
AS REPORTED | Accounting Standards Update 2016-18
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Transfer of cash from restricted accounts, net			6,003
Net cash used in investing activities			(119,066)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents			(12,565)
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			10,512
CLECO POWER
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Net cash used in investing activities	(144,652)		(123,884)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents	(2,374)		(24,016)
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	$ 100,583	[4]	43,939
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			(123,884)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents			(24,016)
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			43,939
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			6,003
Net cash used in investing activities			(117,881)
Net decrease in cash, cash equivalents, restricted cash, and restricted cash equivalents			(18,013)
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			$ 3,469

[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 $116,312, current restricted cash and cash equivalents are $9,945, non-current restricted cash and cash equivalents are $19,080.

[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 $71,579, current restricted cash and cash equivalents are $9,945, non-current restricted cash and cash equivalents are $19,059.

XML

Recent Authoritative Guidance - ASU 2017-07 (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations expenses	$ 30,511	$ 26,235	$ 58,477	$ 55,561
Total operating expenses	235,552	235,391	467,577	444,429
Operating income	63,709	73,270	108,444	114,733
Other expense	(3,745)	(3,281)	(6,928)	(6,219)
Accounting Standards Update 2017-07
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations expenses				55,561
Total operating expenses		235,391		444,429
Operating income		73,270		114,733
Other expense		(3,281)		(6,219)
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 expenses		29,256		61,244
Total operating expenses		238,412		450,114
Operating income		70,249		109,048
Other expense		(260)		(534)
CLECO POWER
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations expenses	26,812	27,649	54,116	57,913
Total operating expenses	229,299	234,120	458,163	441,397
Operating income	72,602	76,667	123,125	123,092
Other expense	$ (3,099)	(2,393)	$ (5,708)	(4,391)
CLECO POWER | Accounting Standards Update 2017-07
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations expenses		27,649		57,913
Total operating expenses		234,120		441,397
Operating income		76,667		123,092
Other expense		(2,393)		(4,391)
CLECO POWER | Accounting Standards Update 2017-07 | AS REPORTED
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Other operations expenses		29,782		61,770
Total operating expenses		236,253		445,254
Operating income		74,534		119,235
Other expense		$ (260)		$ (534)

XML

Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Total regulatory assets, net	$ 339,549	$ 330,582
CLECO POWER
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	260,998	273,220
Total regulatory assets, net	161,337	146,774
CLECO POWER | Mining costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,549	3,823
CLECO POWER | Interest costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,340	4,499
CLECO POWER | AROs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,824	2,762
CLECO POWER | Postretirement costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	136,644	142,764
CLECO POWER | Tree trimming costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,015	7,193
CLECO POWER | Training costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	6,474	6,552
CLECO POWER | Surcredits, net
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	289	2,173
CLECO POWER | AMI deferred revenue requirement
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	3,954	4,227
CLECO POWER | Emergency declarations
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	3,781	4,131
CLECO POWER | Production operations and maintenance expenses
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	5,827	8,625
CLECO POWER | AFUDC equity gross-up
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	71,295	71,205
CLECO POWER | Acquisition/ transaction costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,283	2,336
CLECO POWER | Acquisition/ transaction costs | Coughlin transaction costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	953	968
CLECO POWER | Financing costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,108	8,293
CLECO POWER | MISO integration costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	0	468
CLECO POWER | Corporate franchise tax, net
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	1,500	153
CLECO POWER | MATS costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	0	2,564
CLECO POWER | Non-service cost of postretirement benefits
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,136	0
CLECO POWER | Other
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	26	484
CLECO POWER | Accumulated deferred fuel
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	36,786	13,980
Cleco Holdings | Postretirement costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	20,381	21,375
Cleco Holdings | Financing costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,450	8,623
Cleco Holdings | Fair value of long-term debt
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	142,922	147,145
Cleco Holdings | Debt issuance costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	6,459	6,665
Regulatory liabilities - deferred taxes, net | CLECO POWER
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory liabilities	$ (136,447)	$ (140,426)

XML

Fair Value Accounting - Carrying Value and Estimated Fair Value (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred debt issuance costs not included in the carrying value of long-term debt	$ 11,100	$ 11,600
CARRYING VALUE
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	2,903,190	2,866,955
FAIR VALUE
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	2,865,196	2,921,325
CLECO POWER
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Deferred debt issuance costs not included in the carrying value of long-term debt	8,800	9,100
CLECO POWER | CARRYING VALUE
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	1,410,267	1,369,810
CLECO POWER | FAIR VALUE
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Long-term debt	$ 1,518,752	$ 1,535,234

XML

Fair Value Accounting - Fair Value Measurements and Disclosures (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2018 USD ($) $ / MW	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) $ / MW	Jun. 30, 2017 USD ($)	Dec. 31, 2017 USD ($) $ / MW
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
FTR forward price - per MWh, low | $ / MW	(3.84)		(3.84)		(2.95)
FTR forward price - per MWh, high | $ / MW	7.42		7.42		6.33
Fair value, concentration of risk, amount of money market funds in cash and cash equivalents	$ 112,500,000		$ 112,500,000		$ 111,100,000
Fair value, assets and liabilities, transfers between levels, amount	0		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	9,900,000		9,900,000		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	18,900,000		18,900,000		20,100,000
Measured On A Recurring Basis
Asset description
Institutional money market funds	141,290,000		141,290,000		144,302,000
FTRs	26,077,000		26,077,000		7,396,000
Total assets	167,367,000		167,367,000		151,698,000
Liability description
FTRs	944,000		944,000		352,000
Total liabilities	944,000		944,000		352,000
Price Risk Derivative
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	4,283,000	$ 4,418,000	7,044,000	$ 7,683,000
Unrealized gains (losses)	2,420,000	(2,460,000)	2,420,000	(2,460,000)
Purchases	25,112,000	22,843,000	25,483,000	23,118,000
Settlements	(6,682,000)	(6,858,000)	(9,814,000)	(10,398,000)
Ending balance	25,133,000	$ 17,943,000	25,133,000	$ 17,943,000
QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) | Measured On A Recurring Basis
Asset description
Institutional money market funds	0		0		0
FTRs	0		0		0
Total assets	0		0		0
Liability description
FTRs	0		0		0
Total liabilities	0		0		0
SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | Measured On A Recurring Basis
Asset description
Institutional money market funds	141,290,000		141,290,000		144,302,000
FTRs	0		0		0
Total assets	141,290,000		141,290,000		144,302,000
Liability description
FTRs	0		0		0
Total liabilities	0		0		0
SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | Measured On A Recurring Basis
Asset description
Institutional money market funds	0		0		0
FTRs	26,077,000		26,077,000		7,396,000
Total assets	26,077,000		26,077,000		7,396,000
Liability description
FTRs	944,000		944,000		352,000
Total liabilities	944,000		944,000		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	67,800,000		67,800,000		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	9,900,000		9,900,000		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	18,900,000		18,900,000		20,100,000
CLECO POWER | Measured On A Recurring Basis
Asset description
Institutional money market funds	96,568,000		96,568,000		95,681,000
FTRs	26,077,000		26,077,000		7,396,000
Total assets	122,645,000		122,645,000		103,077,000
Liability description
FTRs	944,000		944,000		352,000
Total liabilities	944,000		944,000		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		0
FTRs	0		0		0
Total assets	0		0		0
Liability description
FTRs	0		0		0
Total liabilities	0		0		0
CLECO POWER | SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) | Measured On A Recurring Basis
Asset description
Institutional money market funds	96,568,000		96,568,000		95,681,000
FTRs	0		0		0
Total assets	96,568,000		96,568,000		95,681,000
Liability description
FTRs	0		0		0
Total liabilities	0		0		0
CLECO POWER | SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) | Measured On A Recurring Basis
Asset description
Institutional money market funds	0		0		0
FTRs	26,077,000		26,077,000		7,396,000
Total assets	26,077,000		26,077,000		7,396,000
Liability description
FTRs	944,000		944,000		352,000
Total liabilities	$ 944,000		$ 944,000		$ 352,000

XML

Fair Value Accounting - Commodity Contracts (Details) $ in Thousands, MWh in Millions	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018 USD ($)	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) MWh	Jun. 30, 2017 USD ($)	Dec. 31, 2017 USD ($) MWh
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument
Commodity-related contracts
Commodity-related contracts, net	$ 25,133		$ 25,133		$ 7,044
Commodity contracts
Net gain (loss) on FTRs recognized in income	10,814	$ 5,620	23,298	$ 10,118
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Energy risk management assets
Commodity-related contracts
FTRs in energy risk management assets	26,077		26,077		7,396
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Other current liabilities
Commodity-related contracts
FTRs in Energy risk management liabilities	944		944		$ 352
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Accumulated deferred fuel
Commodity contracts
Unrealized gains (losses) associated with FTRs not recognized in income on derivatives	2,400	(2,500)	2,400	(2,500)
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Electric operations
Commodity contracts
Gain on FTRs recognized in income	17,841	11,947	35,991	21,110
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Power purchased for utility customers
Commodity contracts
Loss on FTRs recognized in income	$ (7,027)	$ (6,327)	$ (12,693)	$ (10,992)
CLECO POWER
Commodity contracts
Volume of FTRs Held (MWh) | MWh			19.3		9.0

XML

Debt (Details)	Jul. 31, 2018 USD ($)	Apr. 02, 2018 Barge	Mar. 26, 2018 USD ($)	Dec. 18, 2017 USD ($) tranche	Dec. 31, 2012 Barge
Debt Instrument [Line Items]
Number of barges | Barge		42			42
Senior Notes | Note Purchase Agreement
Debt Instrument [Line Items]
Debt amount				$ 175,000,000.0
Number of issuance tranches | tranche				2
Senior Notes | Note Purchase Agreement - 2.94%
Debt Instrument [Line Items]
Debt amount				$ 25,000,000.0
Interest rate, stated percentage (in hundredths)				2.94%
Senior Notes | Note Purchase Agreement - 3.08%
Debt Instrument [Line Items]
Debt amount				$ 100,000,000.0
Interest rate, stated percentage (in hundredths)				3.08%
Senior Notes | Note Purchase Agreement - 3.17%
Debt Instrument [Line Items]
Debt amount			$ 50,000,000.0
Interest rate, stated percentage (in hundredths)			3.17%
Subsequent Event | Notes Payable to Banks | Bank Term Loan Agreement
Debt Instrument [Line Items]
Debt amount	$ 300,000,000.0
Subsequent Event | Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$ 100,000,000.0

XML

Pension Plan and Employee Benefits - Pension Plan and Other Benefits Plan (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
PENSION BENEFITS
Components of periodic benefit costs
Service cost	$ 2,361	$ 2,295	$ 4,753	$ 4,520
Interest cost	5,472	5,467	10,654	10,824
Expected return on plan assets	(5,938)	(5,895)	(11,875)	(12,032)
Amortizations
Prior period service credit	(18)	(18)	(36)	(36)
Net loss (gain)	2,960	2,591	5,921	5,004
Net periodic benefit cost	4,837	4,440	9,417	8,280
OTHER BENEFITS
Components of periodic benefit costs
Service cost	338	385	675	770
Interest cost	357	402	715	805
Expected return on plan assets	0	0	0	0
Amortizations
Prior period service credit	0	0	0	0
Net loss (gain)	5	(2)	10	(5)
Net periodic benefit cost	$ 700	$ 785	$ 1,400	$ 1,570

XML

Pension Plan and Employee Benefits - Narrative (Details) - USD ($)	1 Months Ended	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Mar. 30, 2017	Mar. 29, 2017
PENSION BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		$ 4,837,000	$ 4,440,000	$ 9,417,000	$ 8,280,000
OTHER BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		700,000	785,000	1,400,000	1,570,000
Assets held-in-trust, noncurrent		0		0
SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		1,770,000	1,517,000	3,186,000	3,139,000
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	0	0	(315,000)
CLECO POWER | OTHER BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		800,000	900,000	1,600,000	1,700,000
CLECO POWER | SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		400,000	300,000	700,000	600,000
Other Subsidiaries | PENSION BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Net periodic benefit cost		$ 500,000	$ 500,000	$ 1,000,000	$ 900,000

XML

Pension Plan and Employee Benefits - Current and Non-current Portions of the Other Benefits Liability (Details) - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Defined Benefit Plan Disclosure [Line Items]
Non-current	$ 243,740	$ 242,135
OTHER BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Current	4,061	4,061
Non-current	38,270	39,142
SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Current	4,471	4,471
Non-current	79,487	79,868
CLECO POWER
Defined Benefit Plan Disclosure [Line Items]
Non-current	172,220	173,747
CLECO POWER | OTHER BENEFITS
Defined Benefit Plan Disclosure [Line Items]
Current	3,525	3,525
Non-current	33,302	34,033
CLECO POWER | SERP Benefits
Defined Benefit Plan Disclosure [Line Items]
Current	929	929
Non-current	$ 12,934	$ 16,589

XML

Pension Plan and Employee Benefits - SERP (Details) - SERP Benefits - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		6 Months Ended
	Mar. 31, 2017	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Components of periodic benefit costs
Service cost		$ 166	$ 102	$ 271	$ 247
Interest cost		1,004	820	1,764	1,620
Amortizations
Prior period service credit		(47)	(29)	(81)	(68)
Net loss (gain)		647	624	1,232	1,025
Net periodic benefit cost		1,770	1,517	3,186	2,824
Special/contractual termination benefits	$ 300	0	0	0	315
Net periodic benefit cost		1,770	1,517	3,186	3,139
CLECO POWER
Amortizations
Net periodic benefit cost		$ 400	$ 300	$ 700	$ 600

XML

Pension Plan and Employee Benefits - 401 (K) Plans (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense	$ 1,229	$ 1,204	$ 3,292	$ 2,872
Other Subsidiaries
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense	$ 209	$ 198	$ 611	$ 477

XML

Income Taxes - Effective Tax Rate Reconciliation (Details)	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Effective Income Tax Rate [Line Items]
Effective tax rate	22.90%	38.90%	22.30%	37.80%
CLECO POWER
Effective Income Tax Rate [Line Items]
Effective tax rate	24.20%	39.20%	23.90%	38.10%

XML

Income Taxes - Narrative (Details) - USD ($)	6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 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

XML

Disclosures about Segments (Details) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018 USD ($) entity	Jun. 30, 2017 USD ($)	Jun. 30, 2018 USD ($) entity	Jun. 30, 2017 USD ($)	Dec. 31, 2017 USD ($)
Segment Reporting Information [Line Items]
Number of transmission interconnection facility subsidiaries | entity	2		2
Revenue
Electric operations	$ 294,213	$ 287,435	$ 556,424	$ 521,491
Other operations	18,685	21,465	40,881	38,345
Electric customer credits	(13,637)	(239)	(21,284)	(674)
Affiliate revenue	0	0	0	0
Operating revenue, net	299,261	308,661	576,021	559,162
Depreciation and amortization	41,807	41,552	84,314	82,402
Interest charges	31,909	30,621	63,067	62,339
Interest income	1,427	381	2,211	693
Federal and state income tax expense (benefit)	7,665	16,220	10,528	19,327
Net income (loss)	25,839	25,444	36,700	31,736
Additions to property, plant, and equipment		128,693	135,702	128,693
Equity investment in investee	18,172		18,172		$ 18,172
Goodwill	1,490,797		1,490,797		1,490,797
Total segment assets	6,385,611		6,385,611		6,278,382
Operating Segments | CLECO POWER
Revenue
Electric operations	296,633	289,855	561,264	527,408
Other operations	18,685	20,950	40,880	37,315
Electric customer credits	(13,637)	(239)	(21,284)	(674)
Affiliate revenue	220	221	428	440
Operating revenue, net	301,901	310,787	581,288	564,489
Depreciation and amortization	39,720	39,473	80,109	78,230
Interest charges	18,107	17,411	35,763	35,515
Interest income	1,313	328	1,953	594
Federal and state income tax expense (benefit)	13,710	23,063	21,707	32,918
Net income (loss)	43,020	35,733	69,024	53,587
Additions to property, plant, and equipment		127,297	135,334
Equity investment in investee	18,172		18,172		18,172
Goodwill	1,490,797		1,490,797		1,490,797
Total segment assets	5,807,559		5,807,559		5,679,538
Operating Segments | OTHER
Revenue
Electric operations	(2,420)	(2,420)	(4,840)	(5,917)
Other operations	0	515	1	1,030
Electric customer credits	0	0	0	0
Affiliate revenue	17,273	13,631	32,942	28,365
Operating revenue, net	14,853	11,726	28,103	23,478
Depreciation and amortization	2,086	2,079	4,205	4,172
Interest charges	13,843	13,285	27,392	26,966
Interest income	152	127	342	240
Federal and state income tax expense (benefit)	(6,045)	(6,843)	(11,180)	(13,591)
Net income (loss)	(17,182)	(10,289)	(32,324)	(21,851)
Additions to property, plant, and equipment		1,396	368
Equity investment in investee	0		0		0
Goodwill	0		0		0
Total segment assets	599,216		599,216		619,943
ELIMINATIONS
Revenue
Electric operations	0	0	0	0
Other operations	0	0	0
Electric customer credits	0	0	0	0
Affiliate revenue	(17,493)	(13,852)	(33,370)	(28,805)
Operating revenue, net	(17,493)	(13,852)	(33,370)	(28,805)
Depreciation and amortization	1	0	0	0
Interest charges	(41)	(75)	(88)	(142)
Interest income	(38)	(74)	(84)	(141)
Federal and state income tax expense (benefit)	0	0	1	0
Net income (loss)	1	0	0	$ 0
Additions to property, plant, and equipment		$ 0	0
Equity investment in investee	0		0		0
Goodwill	0		0		0
Total segment assets	$ (21,164)		$ (21,164)		$ (21,099)

XML

Regulation and Rates (Details)		1 Months Ended		6 Months Ended	12 Months Ended	48 Months Ended
	Jan. 01, 2018	Sep. 30, 2016	Nov. 30, 2013	Jun. 30, 2018 USD ($) claim	Dec. 31, 2017 USD ($)	Jun. 30, 2018 USD ($)	Oct. 31, 2017 USD ($)	Feb. 28, 2017 USD ($)
Regulation and Rates [Line Items]
Refund due to customers				$ 25,311,000	$ 4,206,000	$ 25,311,000
Tax Cuts and Jobs Act of 2017, customer refund liability				14,700,000		14,700,000
Federal and state combined statutory tax rate	26.00%				38.00%
CLECO POWER
Regulation and Rates [Line Items]
Refund due to customers				25,311,000	$ 4,206,000	25,311,000
Payments received for capital expenditures subject to refund				$ 4,400,000		4,400,000
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 FRP Monitoring Report, Cost of Service Savings | LPSC
Regulation and Rates [Line Items]
Refund due to customers				1,200,000		$ 1,200,000	$ 1,200,000
CLECO POWER | 2018 FRP Monitoring Report, Earnings-Related Refunds | LPSC
Regulation and Rates [Line Items]
Refund due to customers				5,900,000		5,900,000
CLECO POWER | 2018 FRP Monitoring Report, Cost of Service Savings | LPSC
Regulation and Rates [Line Items]
Refund due to customers				1,200,000		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

XML

Variable Interest Entities (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2017
Variable Interest Entity [Line Items]
Equity investment in investee	$ 18,172		$ 18,172		$ 18,172
Components of Equity Method Investments [Abstract]
Total equity investment in investee	18,172		18,172		18,172
CLECO POWER
Variable Interest Entity [Line Items]
Equity investment in investee	18,172		18,172		18,172
Components of Equity Method Investments [Abstract]
Purchase price	12,873		12,873		12,873
Cash contributions	6,399		6,399		6,399
Dividends	(1,100)		(1,100)		(1,100)
Total equity investment in investee	18,172		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		36,345
Equity Method Investment, Summarized Financial Information [Abstract]
Operating revenue	1,057	$ 532	1,920	$ 1,605
Operating expenses	1,057	532	1,920	1,605
Income before taxes	0	$ 0	$ 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		18,172
Cleco Power’s maximum exposure to loss	$ 18,172		$ 18,172		$ 18,172

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Litigation (Details) $ in Thousands		1 Months Ended					24 Months Ended
	May 22, 2018 USD ($)	Sep. 30, 2016	Jun. 30, 2016 petition	Sep. 30, 2015 USD ($)	Nov. 30, 2014	Nov. 30, 2013	Dec. 31, 2017 USD ($)	Jun. 30, 2018 USD ($)	Feb. 28, 2017 USD ($)
Loss Contingencies [Line Items]
Provision for rate refund							$ 4,206	$ 25,311
Loss contingency, estimate of possible loss								4,600
FERC | MISO Transmission Rates
Loss Contingencies [Line Items]
Public utilities, requested rate increase (decrease), percentage (in hundredths)					0.50%
Gulf Coast Spinning start up costs
Loss Contingencies [Line Items]
Allegations by plaintiff, failure to perform				$ 6,500
Gulf Coast Spinning construction of cotton spinning facility
Loss Contingencies [Line Items]
Allegations by plaintiff, failure to perform				$ 60,000
CLECO POWER
Loss Contingencies [Line Items]
Provision for rate refund							4,206	25,311
CLECO POWER | LPSC 2016-2017 Fuel Audit
Loss Contingencies [Line Items]
Fuel costs							$ 536,200
CLECO POWER | LPSC 2016-2017 EAC Audit
Loss Contingencies [Line Items]
Loss contingency, damages sought, value	$ 30,700
CLECO POWER | LPSC Nov2010-Dec2015 EAC audit
Loss Contingencies [Line Items]
Number of petitions filed with the U.S. Court of Appeals | petition			6
CLECO POWER | FERC | MISO Transmission Rates
Loss Contingencies [Line Items]
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

XML

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Off-Balance Sheet Commitments and Guarantees (Details)	6 Months Ended
	Jun. 30, 2018 USD ($)
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

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Other Commitments (Details)		3 Months Ended	6 Months Ended
	Apr. 02, 2018 USD ($) Barge	Jun. 30, 2018 USD ($)	Jun. 30, 2018 USD ($)	Jul. 31, 2018 USD ($)	Dec. 31, 2012 Barge	Dec. 31, 2008
Other Commitments [Line Items]
Energy investment, useful life			10 years
Tax benefits in excess of capital contributions		$ 18,300,000	$ 18,300,000
Period of recognition of gross investment amortization expense (in years)			10 years
Number of barges | Barge	42				42
Capital leased assets, number of units | 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			$ 285,500,000
Net tax benefits and cash to be received from the Fund			303,800,000
US Bancorp Community Development (USBCDC)
Other Commitments [Line Items]
Membership interest in U.S Bank New Markets Tax Credit Fund (in hundredths)						0.10%
Cleco Power
Other Commitments [Line Items]
Repayments of long-term capital lease obligations		700,000	700,000
Sublease revenue		$ 100,000	$ 100,000
Notes Payable to Banks | Subsequent Event | Bank Term Loan Agreement
Other Commitments [Line Items]
Debt amount				$ 300,000,000.0
Revolving Credit Facility | Subsequent Event
Other Commitments [Line Items]
Line of credit facility, maximum borrowing capacity				$ 100,000,000.0
Savage Inland Marine | Cleco Power
Other Commitments [Line Items]
Loans receivable, related party	$ 16,800,000

XML

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Leased Property under Capital Lease (Details) - CLECO POWER - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Loss Contingencies [Line Items]
Barges	$ 16,800	$ 0
Less: accumulated amortization	280	0
Net capital lease	$ 16,520	$ 0

XML

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees - Minimum Capital Lease Payments (Details) - CLECO POWER $ in Thousands	Jun. 30, 2018 USD ($)
Loss Contingencies [Line Items]
Six months ending Dec. 31, 2018	$ 1,306
Years ending Dec. 31,
2019	2,611
2020	2,611
2021	2,611
2022	2,611
2023	2,611
Thereafter	23,654
Total minimum lease payments	38,015
Less: executory costs	6,021
Net minimum lease payments	31,994
Less: amount representing interest	15,318
Present value of net minimum lease payments	16,676
Current liabilities	529
Non-current liabilities	$ 16,147

XML

Affiliate Transactions (Details) - CLECO POWER - USD ($) $ in Thousands	Jun. 30, 2018	Dec. 31, 2017
Related Party Transaction [Line Items]
Accounts receivable - affiliate	$ 698	$ 1,355
Accounts payable - affiliate	10,701	8,697
Cleco Holdings
Related Party Transaction [Line Items]
Accounts receivable - affiliate	212	743
Accounts payable - affiliate	129	113
Support Group
Related Party Transaction [Line Items]
Accounts receivable - affiliate	486	608
Accounts payable - affiliate	10,572	8,582
Other
Related Party Transaction [Line Items]
Accounts receivable - affiliate	0	4
Accounts payable - affiliate	$ 0	$ 2

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Intangible Assets - Narrative (Details) - USD ($)	3 Months Ended		6 Months Ended		12 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017	Dec. 31, 2008	Dec. 31, 2017
Finite-Lived Intangible Assets [Line Items]
Accumulated amortization	$ 60,909,000		$ 60,909,000			$ 45,948,000
Reduction in revenue on intangible assets for power supply agreements	2,400,000	$ 2,400,000	4,800,000	$ 6,000,000
Trade name
Finite-Lived Intangible Assets [Line Items]
Residual value	0		0
Amortization of intangible assets (less than for Trade name)	100,000	100,000	$ 100,000	100,000
Finite-lived intangible asset, useful life			20 years
Power supply agreements
Finite-Lived Intangible Assets [Line Items]
Residual value	0		$ 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		$ 0
Accumulated amortization	145,830,000		145,830,000		$ 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 for Trade name)	$ 5,500,000	$ 4,700,000	$ 10,000,000	$ 8,200,000
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

XML

Intangible Assets - Summary of Intangible Assets (Details) - USD ($)	Jun. 30, 2018	Dec. 31, 2017	Dec. 31, 2008
Finite-Lived Intangible Assets [Line Items]
Gross carrying amount	$ 160,798,000	$ 160,798,000
Accumulated amortization	(60,909,000)	(45,948,000)
Net intangible assets subject to amortization	99,889,000	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	(145,830,000)	(135,836,000)	$ 0
Net intangible assets subject to amortization	31,707,000	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

XML

Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended		6 Months Ended
	Jun. 30, 2018	Jun. 30, 2017	Jun. 30, 2018	Jun. 30, 2017
Amounts reclassified from accumulated other comprehensive loss
Total other comprehensive income, net of tax	$ 247	$ 60	$ 290	$ (2,131)
TOTAL AOCI
Amounts reclassified from accumulated other comprehensive loss
Total other comprehensive income, net of tax			290
POSTRETIREMENT BENEFIT NET LOSS
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(2,878)	(691)	(2,921)	1,500
Other comprehensive loss before reclassifications
Postretirement benefits adjustment during the period		0		(2,065)
Amounts reclassified from accumulated other comprehensive loss
Amounts reclassified from accumulated other comprehensive loss	247	60	290	(66)
Total other comprehensive income, net of tax	247	60	290	(2,131)
Balances, end of period	(2,631)	(631)	(2,631)	(631)
CLECO POWER
Amounts reclassified from accumulated other comprehensive loss
Total other comprehensive income, net of tax	331	246	628	(121)
CLECO POWER | TOTAL AOCI
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(13,386)	(13,789)	(13,683)	(13,422)
Amounts reclassified from accumulated other comprehensive loss
Total other comprehensive income, net of tax			628
Balances, end of period	(13,055)	(13,543)	(13,055)	(13,543)
CLECO POWER | POSTRETIREMENT BENEFIT NET LOSS
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(8,144)	(8,325)	(8,377)	(7,905)
Other comprehensive loss before reclassifications
Postretirement benefits adjustment during the period		0		(584)
Amounts reclassified from accumulated other comprehensive loss
Amounts reclassified from accumulated other comprehensive loss	267	193	500	357
Total other comprehensive income, net of tax	267	193	500	(227)
Balances, end of period	(7,877)	(8,132)	(7,877)	(8,132)
CLECO POWER | NET LOSS ON CASH FLOW HEDGES
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(5,242)	(5,464)	(5,306)	(5,517)
Amounts reclassified from accumulated other comprehensive loss
Amounts reclassified from accumulated other comprehensive loss	64	53	128	106
Total other comprehensive income, net of tax	64	53	128	106
Balances, end of period	$ (5,178)	$ (5,411)	$ (5,178)	$ (5,411)

XML

Plan of Acquisition (Details)	Feb. 06, 2018 USD ($) MW
Cleco Holdings | Acquisition Loan Facility, NRG South Central Acquisition
Business Acquisition [Line Items]
Debt amount | $	$ 300,000,000.0
Cleco Holdings | Term Loan Facility, NRG South Central Acquisition
Business Acquisition [Line Items]
Debt amount | $	300,000,000.0
Cleco Holdings | Incremental Revolving Facility, NRG Acquisition
Business Acquisition [Line Items]
Debt amount | $	$ 75,000,000.0
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