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 September 30, 2017

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

As of November 9, 2017, Cleco Corporate Holdings LLC has no common stock outstanding. All of the outstanding interest 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	2017 3RD 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)	17
	Notes to the Unaudited Condensed Consolidated Financial Statements	26
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	48
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	62
ITEM 4.	Controls and Procedures	63
PART II	Other Information
ITEM 1.	Legal Proceedings	64
ITEM 1A.	Risk Factors	64
ITEM 4.	Mine Safety Disclosures	64
ITEM 6.	Exhibits	64
	Signatures	65

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CLECO POWER	2017 3RD 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%
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
bcIMC	British Columbia Investment Management Corporation
CCR	Coal combustion by-products or residual
CEO	Chief Executive Officer
CFO	Chief Financial Officer
Cleco	Cleco Holdings and its subsidiaries
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, bcIMC, John Hancock Financial, and other infrastructure investors
Cleco Power	Cleco Power LLC and its subsidiaries, a wholly owned 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
Entergy Mississippi	Entergy Mississippi, Inc.
EPA	U.S. Environmental Protection Agency
ERO	Electric Reliability Organization
ESPP	Employee Stock Purchase Plan
Evangeline	Cleco Evangeline LLC, a wholly owned subsidiary of Midstream
FAC	Fuel Adjustment Clause
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
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)
LED	Louisiana Economic Development
LIBOR	London Interbank Offered Rate
LPSC	Louisiana Public Service Commission
LTIP	Long-Term Incentive Compensation Plan
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

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

ABBREVIATION OR ACRONYM	DEFINITION
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
Oxbow	Oxbow Lignite Company, LLC, 50% owned by Cleco Power and 50% owned by SWEPCO
Perryville	Perryville Energy Partners, L.L.C., a wholly owned subsidiary of Cleco Holdings
Predecessor	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.
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
SSR	System Support Resource
Successor	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.
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.
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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CLECO POWER	2017 3RD QUARTER FORM 10-Q

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,

• 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, 

• 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, 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 tax laws), changes in tax rates, disallowances of 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,

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

• 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, 

• nonperformance by and creditworthiness of the guarantor counterparty of the NMTC Fund, 

• 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, please see Part I, Item 1A, “Risk Factors” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2016.

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
CLECO POWER	2017 3RD 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, 2016. 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	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016
Operating revenue
Electric operations	$	317,589		$	323,707
Other operations	21,282			18,976
Gross operating revenue	338,871			342,683
Electric customer credits	(372		)	177
Operating revenue, net	338,499			342,860
Operating expenses
Fuel used for electric generation	103,217			101,908
Power purchased for utility customers	39,355			36,058
Other operations	27,957			35,361
Maintenance	18,031			19,412
Depreciation and amortization	42,228			42,535
Taxes other than income taxes	12,414			12,574
Merger transaction and commitment costs	185			1,869
Total operating expenses	243,387			249,717
Operating income	95,112			93,143
Interest income	354			318
Allowance for equity funds used during construction	2,096			1,308
Other income	2,557			658
Other expense	(1,299		)	(248		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	31,110			32,233
Allowance for borrowed funds used during construction	(648		)	(375		)
Total interest charges	30,462			31,858
Income before income taxes	68,358			63,321
Federal and state income tax expense	23,054			23,700
Net income	$	45,304		$	39,621
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO
CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016
Net income	$	45,304		$	39,621
Other comprehensive loss, net of tax
Postretirement benefits loss (net of tax benefits of $26 and $1,442, respectively)	(44		)	(2,305		)
Total other comprehensive loss, net of tax	(44		)	(2,305		)
Comprehensive income, net of tax	$	45,260		$	37,316
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Income (Unaudited)
	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Operating revenue
Electric operations	$	839,080		$	553,634		$	281,154
Other operations	59,627			33,110			19,080
Gross operating revenue	898,707			586,744			300,234
Electric customer credits	(1,045		)	(381		)	(364		)
Operating revenue, net	897,662			586,363			299,870
Operating expenses
Fuel used for electric generation	261,063			168,159			96,378
Power purchased for utility customers	114,675			60,439			27,249
Other operations	89,201			59,633			33,563
Maintenance	66,955			42,317			29,813
Depreciation and amortization	124,630			76,695			44,076
Taxes other than income taxes	36,790			22,953			14,611
Merger transaction and commitment costs	187			173,172			34,912
Gain on sale of asset	—			—			(1,095		)
Total operating expenses	693,501			603,368			279,507
Operating income (loss)	204,161			(17,005		)	20,363
Interest income	1,046			515			265
Allowance for equity funds used during construction	4,446			2,057			723
Other income	4,402			2,395			870
Other expense	(1,833		)	(435		)	(590		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	94,077			58,926			22,330
Allowance for borrowed funds used during construction	(1,277		)	(603		)	(207		)
Total interest charges	92,800			58,323			22,123
Income (loss) before income taxes	119,422			(70,796		)	(492		)
Federal and state income tax expense (benefit)	42,381			(28,502		)	3,468
Net income (loss)	$	77,041		$	(42,294	)	$	(3,960	)
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Net income (loss)	$	77,041		$	(42,294	)	$	(3,960	)
Other comprehensive (loss) income, net of tax
Postretirement benefits (loss) gain (net of tax benefit of $1,359 and $1,442 and tax expense of $367, respectively)	(2,175		)	(2,305		)	587
Amortization of interest rate derivatives to earnings (net of tax expense of $0, $0, and $37, respectively)	—			—			60
Total other comprehensive (loss) income, net of tax	(2,175		)	(2,305		)	647
Comprehensive income (loss), net of tax	$	74,866		$	(44,599	)	$	(3,313	)
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2017			AT DEC. 31, 2016
Assets
Current assets
Cash and cash equivalents	$	6,127		$	23,077
Restricted cash and cash equivalents	8,874			23,084
Customer accounts receivable (less allowance for doubtful accounts of $2,102 in 2017 and $7,199 in 2016)	78,313			56,780
Other accounts receivable	33,934			19,778
Unbilled revenue	38,912			34,268
Fuel inventory, at average cost	51,847			46,410
Materials and supplies, at average cost	84,522			81,818
Energy risk management assets	13,425			7,884
Accumulated deferred fuel	21,057			20,787
Cash surrender value of company-/trust-owned life insurance policies	81,165			77,225
Prepayments	6,553			7,813
Regulatory assets	27,636			26,803
Other current assets	410			1,315
Total current assets	452,775			427,042
Property, plant, and equipment
Property, plant, and equipment	3,556,775			3,476,581
Accumulated depreciation	(162,040		)	(75,816		)
Net property, plant, and equipment	3,394,735			3,400,765
Construction work in progress	163,423			78,577
Total property, plant, and equipment, net	3,558,158			3,479,342
Equity investment in investee	18,172			18,672
Goodwill	1,490,797			1,490,797
Prepayments	1,887			4,731
Restricted cash and cash equivalents	24,547			23,410
Regulatory assets - deferred taxes, net	240,431			237,449
Regulatory assets	430,893			454,644
Net investment in direct financing lease	13,381			13,420
Intangible assets	121,269			142,634
Tax credit fund investment, net	10,409			11,888
Other deferred charges	34,982			39,115
Total assets	$	6,397,701		$	6,343,144
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.
(Continued on next page)

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2017			AT DEC. 31, 2016
Liabilities and member’s equity
Liabilities
Current liabilities
Short-term debt	$	6,470		$	—
Long-term debt due within one year	19,193			19,715
Accounts payable	99,138			112,087
Customer deposits	58,018			56,599
Provision for rate refund	3,734			3,974
Provision for merger commitments	4,945			14,371
Taxes payable, net	26,894			3,942
Interest accrued	38,656			14,783
Energy risk management liabilities	538			201
Deferred compensation	11,604			11,654
Other current liabilities	21,309			14,850
Total current liabilities	290,499			252,176
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	1,075,869			1,033,055
Accumulated deferred investment tax credits	2,254			2,751
Postretirement benefit obligations	230,203			223,003
Restricted storm reserve	18,189			17,385
Other deferred credits	29,430			29,440
Total long-term liabilities and deferred credits	1,355,945			1,305,634
Long-term debt, net	2,713,583			2,738,571
Total liabilities	4,360,027			4,296,381
Commitments and contingencies (Note 12)
Member’s equity
Membership interest	1,985,421			2,069,376
Retained earnings/(Accumulated deficit)	52,928			(24,113		)
Accumulated other comprehensive (loss) income	(675		)	1,500
Total member’s equity	2,037,674			2,046,763
Total liabilities and member’s equity	$	6,397,701		$	6,343,144
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Cash Flows (Unaudited)
	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Operating activities
Net income (loss)	$	77,041		$	(42,294	)	$	(3,960	)
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	140,433			104,561			45,869
Gain on sale of asset	—			—			(1,095		)
Provision for doubtful accounts	2,694			1,932			1,212
Unearned compensation expense	2,809			769			3,276
Allowance for equity funds used during construction	(4,446		)	(2,056		)	(724		)
Deferred income taxes	41,192			(25,681		)	2,219
Deferred fuel costs	4,231			(11,489		)	977
Cash surrender value of company-/trust-owned life insurance	(3,940		)	(2,198		)	(840		)
Changes in assets and liabilities
Accounts receivable	(44,139		)	(23,157		)	(1,865		)
Accounts receivable, affiliate	12			(3,794		)	—
Unbilled revenue	(4,643		)	(13,643		)	563
Fuel inventory and materials and supplies	(6,885		)	19,464			19,312
Prepayments	5,509			(236		)	2,395
Accounts payable	(22,325		)	(15,294		)	8,348
Customer deposits	9,317			5,421			3,342
Provision for merger commitments	(9,244		)	40,357			—
Postretirement benefit obligations	3,789			2,267			9,746
Regulatory assets and liabilities, net	9,430			9,640			5,178
Other deferred accounts	(6,546		)	(2,065		)	6,878
Taxes accrued	22,233			5,006			10,820
Interest accrued	23,772			13,479			17,909
Other operating	6,595			5,714			219
Net cash provided by operating activities	246,889			66,703			129,779
Investing activities
Additions to property, plant, and equipment	(185,609		)	(102,677		)	(42,392		)
Allowance for equity funds used during construction	4,446			2,056			724
Proceeds from sale of property	590			263			1,932
Contributions to equity investment in investee	—			—			(2,450		)
Return of equity investment in tax credit fund	1,223			901			476
Transfer of cash from (to) restricted accounts, net	13,073			(33,943		)	4,847
Other investing	7			137			53
Net cash used in investing activities	(166,270		)	(133,263		)	(36,810		)
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.
(Continued on next page)

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Cash Flows (Unaudited)
	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Financing activities
Proceeds from short-term debt, net	6,470			—			—
Draws on credit facilities	134,000			15,000			3,000
Payments on credit facilities	(134,000		)	(15,000		)	(10,000		)
Issuance of long-term debt	—			1,350,000			—
Repayment of long-term debt	(17,896		)	(1,358,268		)	(8,546		)
Payment of financing costs	(369		)	(6,860		)	(43		)
Dividends paid on common stock	—			(572		)	(24,579		)
Contribution from member	—			100,720			—
Distributions to member	(83,955		)	(56,000		)	—
Other financing	(1,819		)	(1,220		)	(717		)
Net cash (used in) provided by financing activities	(97,569		)	27,800			(40,885		)
Net (decrease) increase in cash and cash equivalents	(16,950		)	(38,760		)	52,084
Cash and cash equivalents at beginning of period	23,077			120,330			68,246
Cash and cash equivalents at end of period	$	6,127		$	81,570		$	120,330
Supplementary cash flow information
Interest paid, net of amount capitalized	$	64,555		$	42,963		$	2,478
Income taxes (refunded) paid, net	$	(6	)	$	256		$	(481	)
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	13,083		$	15,853		$	10,619
Non-cash additions to property, plant, and equipment	$	3,015		$	—		$	—
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited)
(THOUSANDS)	MEMBERSHIP INTEREST			(ACCUMULATED DEFICIT)  /RETAINED EARNINGS			AOCI			TOTAL MEMBER’S EQUITY
Balances, Dec. 31, 2016	$	2,069,376		$	(24,113	)	$	1,500		$	2,046,763
Distributions to member	(83,955		)	—			—			(83,955		)
Net income	—			77,041			—			77,041
Other comprehensive loss, net of tax	—			—			(2,175		)	(2,175		)
Balances, Sept. 30, 2017	$	1,985,421		$	52,928		$	(675	)	$	2,037,674
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 3RD 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, 2016. 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	2017 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016
Operating revenue
Electric operations	$	320,009		$	326,281
Other operations	20,768			18,460
Affiliate revenue	209			213
Gross operating revenue	340,986			344,954
Electric customer credits	(372		)	177
Operating revenue, net	340,614			345,131
Operating expenses
Fuel used for electric generation	103,217			101,908
Power purchased for utility customers	39,355			36,058
Other operations	28,680			35,886
Maintenance	17,812			19,326
Depreciation and amortization	40,049			40,353
Taxes other than income taxes	12,008			12,180
Total operating expenses	241,121			245,711
Operating income	99,493			99,420
Interest income	332			264
Allowance for equity funds used during construction	2,096			1,308
Other income	1,463			629
Other expense	(1,299		)	(445		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	17,789			19,552
Allowance for borrowed funds used during construction	(648		)	(375		)
Total interest charges	17,141			19,177
Income before income taxes	84,944			81,999
Federal and state income tax expense	30,092			29,427
Net income	$	54,852		$	52,572
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016
Net income	$	54,852	$	52,572
Other comprehensive income, net of tax
Postretirement benefits gain (net of tax expense of $104 in 2017 and $1,364 in 2016)	167		2,180
Amortization of interest rate derivatives to earnings (net of tax expense of $33 in 2017 and 2016)	53		53
Total other comprehensive income, net of tax	220		2,233
Comprehensive income, net of tax	$	55,072	$	54,805
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016
Operating revenue
Electric operations	$	847,417		$	839,593
Other operations	58,083			50,638
Affiliate revenue	649			669
Gross operating revenue	906,149			890,900
Electric customer credits	(1,045		)	(745		)
Operating revenue, net	905,104			890,155
Operating expenses
Fuel used for electric generation	261,063			264,537
Power purchased for utility customers	114,675			87,688
Other operations	90,453			94,566
Maintenance	66,496			71,818
Depreciation and amortization	118,280			115,196
Taxes other than income taxes	35,412			36,096
Merger commitment costs	—			151,501
Gain on sale of asset	—			(1,095		)
Total operating expenses	686,379			820,307
Operating income	218,725			69,848
Interest income	926			590
Allowance for equity funds used during construction	4,446			2,780
Other income	1,839			828
Other expense	(1,833		)	(1,082		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	53,931			58,587
Allowance for borrowed funds used during construction	(1,277		)	(810		)
Total interest charges	52,654			57,777
Income before income taxes	171,449			15,187
Federal and state income tax expense	63,010			2,965
Net income	$	108,439		$	12,222
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016
Net income	$	108,439		$	12,222
Other comprehensive income, net of tax
Postretirement benefits (loss) gain (net of tax benefit of $38 in 2017 and tax expense of $1,602 in 2016)	(60		)	2,561
Amortization of interest rate derivatives to earnings (net of tax expense of $99 in 2017 and 2016)	159			159
Total other comprehensive income, net of tax	99			2,720
Comprehensive income, net of tax	$	108,538		$	14,942
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2017			AT DEC. 31, 2016
Assets
Utility plant and equipment
Property, plant, and equipment	$	4,858,764		$	4,790,565
Accumulated depreciation	(1,687,337		)	(1,618,241		)
Net property, plant, and equipment	3,171,427			3,172,324
Construction work in progress	162,500			77,306
Total utility plant and equipment, net	3,333,927			3,249,630
Current assets
Cash and cash equivalents	4,227			21,482
Restricted cash and cash equivalents	8,874			23,084
Customer accounts receivable (less allowance for doubtful accounts of $2,102 in 2017 and $7,199 in 2016)	78,313			56,780
Accounts receivable - affiliate	1,545			1,406
Other accounts receivable	33,676			19,457
Taxes receivable, net	—			12,490
Unbilled revenue	38,912			34,268
Fuel inventory, at average cost	51,847			46,410
Materials and supplies, at average cost	84,522			81,818
Energy risk management assets	13,425			7,884
Accumulated deferred fuel	21,057			20,787
Cash surrender value of company-owned life insurance policies	20,216			20,018
Prepayments	5,367			5,892
Regulatory assets	18,779			17,721
Other current assets	—			577
Total current assets	380,760			370,074
Equity investment in investee	18,172			18,672
Prepayments	1,887			4,731
Restricted cash and cash equivalents	24,526			23,389
Regulatory assets - deferred taxes, net	240,431			237,449
Regulatory assets	253,146			268,016
Intangible asset	45,636			58,473
Other deferred charges	33,020			37,014
Total assets	$	4,331,505		$	4,267,448
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.
(Continued on next page)

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CLECO POWER
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Liabilities and member’s equity
Member’s equity	$	1,568,740	$	1,535,202
Long-term debt, net	1,216,967		1,235,056
Total capitalization	2,785,707		2,770,258
Current liabilities
Short-term debt	6,470		—
Long-term debt due within one year	19,193		19,715
Accounts payable	92,522		101,874
Accounts payable - affiliate	8,293		7,190
Customer deposits	58,018		56,599
Provision for rate refund	3,734		3,974
Provision for merger commitments	4,945		14,371
Taxes payable, net	19,487		—
Interest accrued	20,348		7,141
Energy risk management liabilities	538		201
Other current liabilities	15,659		9,951
Total current liabilities	249,207		221,016
Commitments and contingencies (Note 12)
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	1,084,482		1,068,592
Accumulated deferred investment tax credits	2,254		2,751
Postretirement benefit obligations	164,183		159,107
Restricted storm reserve	18,189		17,385
Other deferred credits	27,483		28,339
Total long-term liabilities and deferred credits	1,296,591		1,276,174
Total liabilities and member’s equity	$	4,331,505	$	4,267,448
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER
Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017				2016
Operating activities
Net income	$	108,439			$	12,222
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	123,911				120,703
Gain on sale of asset	—				(1,095		)
Provision for doubtful accounts	2,592				3,014
Unearned compensation expense	1,479			—	1,394
Allowance for equity funds used during construction	(4,446		)		(2,780		)
Deferred income taxes	12,847				5,201
Deferred fuel costs	4,231				(10,512		)
Changes in assets and liabilities
Accounts receivable	(44,115		)		(24,378		)
Accounts receivable, affiliate	1,221				1,647
Unbilled revenue	(4,643		)		(13,080		)
Fuel inventory and materials and supplies	(6,885		)		38,776
Prepayments	4,774				1,368
Accounts payable	(19,648		)		(9,485		)
Accounts payable, affiliate	611				(2,583		)
Customer deposits	9,317				8,763
Provision for merger commitments	(9,244		)		40,357
Postretirement benefit obligations	3,673				3,656
Regulatory assets and liabilities, net	7,939				13,893
Other deferred accounts	(6,093		)		4,813
Taxes accrued	31,258				1,607
Interest accrued	13,207				15,147
Other operating	5,537				5,818
Net cash provided by operating activities	235,962				214,466
Investing activities
Additions to property, plant, and equipment	(183,604		)		(144,637		)
Allowance for equity funds used during construction	4,446				2,780
Proceeds from sale of property	590				2,195
Contributions to equity investment in investee	—				(2,450		)
Transfer of cash from (to) restricted accounts, net	13,073				(29,096		)
Other investing	637				190
Net cash used in investing activities	(164,858		)		(171,018		)
Financing activities
Proceeds from short-term debt, net	6,470				—
Draws on credit facility	106,000				15,000
Payments on credit facility	(106,000		)		(15,000		)
Repayment of long-term debt	(17,896		)		(16,814		)
Contributions from parent	—				50,000
Distributions to parent	(75,000		)		(85,000		)
Other financing	(1,933		)		(2,070		)
Net cash used in financing activities	(88,359		)		(53,884		)
Net decrease in cash and cash equivalents	(17,255		)		(10,436		)
Cash and cash equivalents at beginning of period	21,482				65,705
Cash and cash equivalents at end of period	$	4,227			$	55,269
Supplementary cash flow information
Interest paid, net of amount capitalized	$	36,241			$	40,153
Income taxes refunded, net	$	—			$	(485	)
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	13,072			$	15,837
Non-cash additions to property, plant, and equipment	$	3,015			$	—
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER
Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited)
(THOUSANDS)	MEMBER’S EQUITY			AOCI			TOTAL  MEMBER’S EQUITY
Balances, Dec. 31, 2016	$	1,548,624		$	(13,422	)	$	1,535,202
Distributions to parent	(75,000		)	—			(75,000		)
Net income	108,439			—			108,439
Other comprehensive income, net of tax	—			99			99
Balances, Sept. 30, 2017	$	1,582,063		$	(13,323	)	$	1,568,740
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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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	Business Combinations	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	Accumulated Other Comprehensive Loss	Cleco and Cleco Power
Note 15	Subsequent Event	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, 2016.

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.”

On April 13, 2016, Cleco Holdings completed its merger with Merger Sub whereby Merger Sub 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, as a direct, wholly owned subsidiary of Cleco Group and an indirect, wholly owned subsidiary of Cleco Partners. At the effective time of the Merger, each outstanding share of Cleco Corporation common stock, par value $1.00 per share (other than shares that were owned by Cleco Corporation, Cleco Partners, Merger Sub, or any other direct or indirect wholly owned subsidiary of Cleco Partners or Cleco Corporation), were cancelled and were converted into the right to receive $55.37 per share in cash, without interest, with all dividends payable before the effective time of the Merger.

Cleco Holdings accounted for the merger transaction by applying the acquisition method of accounting. The objective of the acquisition method is to establish a new accounting basis for the acquiree, Cleco Holdings and its subsidiaries, and requires the acquirer, Cleco Group, to recognize and measure the acquiree’s assets and liabilities at fair value as of the acquisition date. Cleco Power’s assets and liabilities were recorded at historical cost since Cleco did not elect pushdown accounting at the Cleco Power level. The financial statements and accompanying footnotes for Cleco have been segregated to present pre-merger activity as the “Predecessor” and post-merger activity as the “Successor.” The predecessor period is not comparable to the successor period.

Goodwill

Goodwill is the excess of the purchase price (consideration transferred and liabilities assumed) over the estimated fair value of net assets of the acquired business and is not subject

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to amortization. On April 13, 2016, in connection with the completion of the Merger, Cleco recognized goodwill of $1.49 billion. Management assigned goodwill to Cleco’s reportable segment, Cleco Power. Goodwill is required to be tested for impairment at the reporting segment level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting segment below its carrying value. Application of the goodwill impairment test requires significant judgments, including the identification of reporting segments, assignments of assets and liabilities to reporting segments, assignment of goodwill to reporting segments, and the determination of the fair value of the reporting segments. Management has determined that Cleco Power is Cleco’s only reporting segment.

Cleco conducted its 2017 annual impairment test using an August 1, 2017, measurement date. The fair value of Cleco’s reporting segment, Cleco Power, was estimated using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market approach, which estimates fair value based on market comparables within the utility and energy industries. Significant assumptions used in these fair value estimates include estimation of future cash flows, long-term rate of growth, the selection of comparable companies, and weighted-average cost of capital (WACC) or discount rate. Changes in these assumptions could materially affect the determination of fair value and goodwill impairment at Cleco Power. Based on the tests performed, management has determined that there was no impairment of Cleco Power’s goodwill as of August 1, 2017.

Management estimated the fair value of Cleco Power’s equity to be $3.34 billion at the August 1, 2017, measurement date. The carrying value of Cleco Power’s equity was approximately $3.25 billion with the excess of the fair value over the carrying value representing 3% or $89.5 million. There were no accumulated impairment charges.

The fair value estimate is particularly sensitive to WACC. WACC takes into account both the after-tax cost of debt and the cost of equity. WACC used for calculating the fair values as of August 1, 2017, was 5.2%. A downgrade in Cleco Power’s debt ratings or a decrease in income tax rates could increase Cleco Power’s after-tax cost of debt. In addition, an increase in interest rates or return required by investors in equity markets could increase Cleco Power’s cost of equity. Any increase in the cost of equity or the cost of debt could materially impact Cleco Power’s fair value estimate. A WACC of 5.1% or 5.3% would have resulted in fair value calculations of $3.43 billion and $3.25 billion, respectively.

The fair value estimate is also sensitive to long-term cash flow growth rates applicable to periods beyond management’s five-year business plan. Management assumed a long-term cash flow growth rate of 2.5% based on historical and projected consumer price inflation, economic indicators, and projected industry growth. Any change in the expected terminal cash flow growth rate could materially impact Cleco Power’s fair value estimate. A terminal cash flow growth rate of 2.4% or 2.6% would have resulted in a fair value calculation of $3.25 billion and $3.43 billion, respectively.

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 SEPT. 30, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,798	$	9,213
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	3,876		12,671
Total current	8,874		23,084
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	17,999		17,379
Cleco Power’s charitable contributions	3,640		4,179
Cleco Power’s rate credit escrow	2,887		1,831
Total non-current	24,547		23,410
Total restricted cash and cash equivalents	$	33,421	$	46,494

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,798	$	9,213
Charitable contributions	1,200		1,200
Rate credit escrow	3,876		12,671
Total current	8,874		23,084
Non-current
Future storm restoration costs	17,999		17,379
Charitable contributions	3,640		4,179
Rate credit escrow	2,887		1,831
Total non-current	24,526		23,389
Total restricted cash and cash equivalents	$	33,400	$	46,473

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, 2016, to September 30, 2017, was due to Cleco Katrina/Rita using $17.9 million for scheduled storm recovery bond principal payments and $3.6 million for related interest payments, partially offset by collections of $16.1 million net of administration fees.

Included in the Merger Commitments were $6.0 million of charitable contributions to be disbursed over five years and $136.0 million of rate credits to eligible customers. In April 2016, in accordance with the Merger Commitments, Cleco Power established the charitable contribution fund and also deposited the rate credit funds into an escrow account. In April 2016, the LPSC voted to issue the rate credits equally to customers with service as of June 30, 2016, beginning in July 2016. As of September 30, 2017, $1.2 million of the charitable contributions and $129.4 million of the rate credits had been released from restricted cash.

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

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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. In June 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. This proposal was submitted to the LPSC on July 28, 2017. An ALJ was assigned to the docket and a status conference was held on October 3, 2017. A procedural schedule was determined and management expects a final determination in the second quarter of 2018. There were no open natural gas positions at September 30, 2017, or December 31, 2016.

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 September 30, 2017, Cleco Power’s Condensed Consolidated Balance Sheets reflected the fair value of open FTR positions of $13.4 million in Energy risk management assets and $0.5 million in Energy risk management liabilities, compared to $7.9 million in Energy risk management assets and $0.2 million in Energy risk management liabilities at December 31, 2016. 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.

Stock-Based Compensation

Prior to the completion of the Merger, Cleco had two stock-based compensation plans: the ESPP and the LTIP. As a result of the completion of the Merger, both stock-based compensation plans were terminated.

Pursuant to the terms of the LTIP, certain officers, key employees, and directors of Cleco were eligible to be granted stock options, restricted stock, also known as non-vested stock, common stock equivalents, and stock appreciation rights. During the predecessor period January 1, 2016, through April 12, 2016, Cleco granted no shares of non-vested stock pursuant to the LTIP. As a result of the Merger on April 13, 2016, all unvested shares outstanding under the LTIP that were granted prior to January 1, 2015, vested at target and were paid out in cash to plan participants. Unvested shares that were granted during 2015 were prorated to the target amount and paid out in cash to plan participants in accordance with the terms of the Merger Agreement.

During the predecessor period January 1, 2016, through April 12, 2016, Cleco reported pretax compensation expense of $3.2 million on non-vested stock with a related tax benefit of $1.2 million. In April 2016, Cleco incurred $2.3 million of merger expense due to the accelerated vesting of the LTIP shares for the predecessor period. For more information about the Merger, see Note 2 — “Business Combinations.”

During the nine months ended September 30, 2016, Cleco Power reported pretax compensation expense of $1.0 million on non-vested stock with a related tax benefit of $0.4 million.

Note 2 — Business Combinations

Regulatory Matters

On March 28, 2016, the LPSC approved the Merger. The LPSC’s written order approving the Merger was issued on April 7, 2016. Approval of the Merger was conditioned upon certain commitments, including $136.0 million of customer rate credits, a $7.0 million one-time contribution for economic development in Cleco Power’s service territory to be administered by the LED, $6.0 million of charitable contributions to be disbursed over five years, and $2.5 million of contributions for economic development for Louisiana state and local organizations to be disbursed over five years. These commitment costs were accrued on April 13, 2016. In addition, the Merger Commitments also included $1.2 million of annual

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refunds to customers representing cost savings due to the Merger. For more information, see Note 10 — “Regulation and Rates.”

Accounting for the Merger Transaction

The total purchase price consideration was approximately $3.36 billion, which consisted of cash paid to Cleco Corporation shareholders of $3.35 billion and cash paid for Cleco LTIP equity awards of $9.5 million. There were no remaining LTIP equity awards as of the close of the Merger.

Pushdown accounting was applied to Cleco, and accordingly, the Cleco consolidated assets acquired and liabilities assumed were recorded on April 13, 2016, at their fair values as follows:

Purchase Price Allocation
(THOUSANDS)	AT APR. 13, 2016
Current assets	$	455,016
Property, plant, and equipment, net	3,432,144
Goodwill	1,490,797
Other long-term assets	1,023,487
Less
Current liabilities	228,515
Net deferred income tax liabilities	1,059,939
Other deferred credits	279,379
Long-term debt, net	1,470,126
Total purchase price	$	3,363,485

Cleco Power’s assets and liabilities were recorded at historical cost since Cleco did not elect pushdown accounting at the Cleco Power level.

The following table presents the fair value adjustments to Cleco’s balance sheet and recognition of goodwill:

(THOUSANDS)	AT APR. 13, 2016
Property, plant, and equipment	$	(1,334,932	)
Accumulated depreciation	$	(1,565,776	)
Goodwill	$	1,490,797
Intangible assets	$	91,826
Regulatory assets	$	250,409
Deferred income tax liabilities	$	126,853
Other deferred credits	$	21,175
Long-term debt	$	198,599

Most of the carrying values of Cleco’s assets and liabilities were determined to be stated at fair value at the Merger date, considering that most of these assets are subject to regulation by the LPSC and FERC. Under such regulation, rates charged to customers are established by a regulator to provide for recovery of costs and a fair return on rate base and are generally measured at historical cost. As such, a market participant would not expect to recover any more or less than the carrying value of the assets. Prior to the Merger, the Coughlin step-up value was not recorded on Cleco’s Condensed Consolidated Balance Sheet due to the accounting treatment for the transfer of that asset in March 2014. However, the recovery of the step-up value of the Coughlin asset was approved by the LPSC for recovery in base rates, including a return on rate base. On the date of the Merger, the step-up value for the Coughlin asset was recognized on Cleco’s Condensed Consolidated Balance Sheet since Cleco Power is able to earn a return on and recover these costs from its customers. The beginning balance

of fixed depreciable assets was shown net at the date of the Merger, as no accumulated depreciation existed on the date of the Merger.

The excess of the purchase price over the estimated fair value of assets acquired and the liabilities assumed was $1.49 billion, which was recognized as goodwill by Cleco Holdings at the Merger date. The goodwill represents the potential long-term return of Cleco to its member. Management has assigned goodwill to Cleco’s reportable segment, Cleco Power.

A fair value adjustment was recorded on Cleco’s Condensed Consolidated Balance Sheet to reflect the valuation of the Cleco trade name. This adjustment is included in Intangible assets on Cleco’s Condensed Consolidated Balance Sheet. The valuation of the trade name was estimated by applying the relief-from-royalty method under the income approach. This valuation method is based on the premise that, in lieu of ownership of the asset, a company would be willing to pay a royalty to a third-party for the use of that asset. The owner of the asset is spared this cost, and the value of the asset is estimated by the cost savings. The projected revenue attributed to the trade name was based on projections of the value of Cleco’s wholesale contracts. The trade name is being amortized over 20 years. The amortization of the Cleco trade name is included in Depreciation and amortization on Cleco’s Condensed Consolidated Statement of Income.

On the date of the Merger, fair value adjustments were recorded on Cleco’s Condensed Consolidated Balance Sheet for the difference between the contract price and the market price of long-term wholesale power supply agreements. These adjustments are classified as Intangible assets on Cleco’s Condensed Consolidated Balance Sheet. The valuation of the power supply agreements was estimated using the income approach. The income approach is based upon discounted projected future cash flows associated with the underlying contracts. The intangible assets for the power supply agreements are being amortized over the remaining term of each applicable contract. The amortization of the power supply agreements is included in Electric operations on Cleco’s Condensed Consolidated Statement of Income.

The net increase in deferred tax liabilities on Cleco’s Condensed Consolidated Balance Sheet represents the differences between the assigned fair values of assets acquired and their related income tax basis, net of a deferred tax asset representing the net operating loss carryforward that will be utilized in future periods. As the underlying asset assigned fair values are amortized, the related deferred tax liabilities will be included in income tax expense. Goodwill is not deductible for income tax purposes; therefore, no deferred income tax assets or liabilities were recognized for goodwill.

Other fair value adjustments were recorded for long-term debt, postretirement benefit remeasurements and deferred losses, and interest rate derivative settlement gains and losses. These fair value adjustments are subject to rate regulation, but do not earn a return. In these instances, a corresponding regulatory asset was established, as the underlying utility asset or liability amounts are recoverable from or refundable to customers at historical cost through the rate setting process. These regulatory assets established to offset fair value adjustments are amortized in amounts and over time frames consistent with the realization or settlement of the fair value adjustments.

The valuations performed in the second quarter of 2016 to estimate the fair value of assets acquired and liabilities assumed were considered preliminary as a result of the short

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time period between the closing of the Merger and the end of the second quarter of 2016. During the third quarter of 2016, valuations were performed for the valuation and assessment of the postretirement benefit plans as of April 13, 2016, and the economic useful life of the Cleco trade name. Cleco completed its evaluation and determination of the fair value of certain assets and liabilities acquired as of December 31, 2016. There were no adjustments to those amounts during the nine months ended September 30, 2017. While management believes the positions reflected on the income tax returns are reasonable, the returns have not been audited by the applicable taxing authorities.

Note 3 — Recent Authoritative Guidance

The Registrants adopted, or will adopt, the recent authoritative guidance listed below on their respective effective dates.

In May 2014, FASB amended the accounting guidance for revenue recognition. The amended guidance affects entities that enter into contracts for the transfer of non-financial 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. Under the new guidance, an entity must identify the performance obligations in a contract and the transaction price, and allocate the price to specific performance obligations to recognize the revenue when the obligation is completed. The amendments in this update also require extensive disclosure of sufficient information to allow users to understand the nature, amount, timing, and uncertainty of revenue and cash flow arising from contracts. Additional disclosure requirements include disaggregated revenue, reconciliation of contract balances, the entity’s performance obligations, significant judgments used, costs to obtain or fulfill a contract and the use of practical expedients. The standard will be effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Reporting entities have the option of using either a full retrospective or a modified retrospective approach. Under the full retrospective approach, companies will apply rules to contracts in all reporting periods presented, subject to certain allowable exceptions. Under the modified retrospective approach, companies will apply the rules to all contracts existing as of January 1, 2018, recognizing in beginning retained earnings an adjustment for the cumulative effect of the change and providing additional disclosures comparing results to previous rules. Cleco intends to implement the amended guidance in January 2018 using the modified retrospective approach.

Upon initial evaluation, key changes in the standard that management is assessing for potential areas of impact include accounting for contract modifications, contracts with pricing provisions that may require it to recognize revenue at prices other than the contract price (e.g., straight-line or estimated future market prices), and accounting for alternative revenue programs. Management has not identified any impacts that would have a material impact on the results of operations, financial condition, or cash flows of the Registrants. Management expects most of Cleco’s revenue to be in scope of the new guidance. The majority of sales, including energy provided to residential customers, are from tariff offerings that provide electricity supplied and billed in that period. As such,

management does not expect that there will be a significant shift in the timing or pattern of revenue recognition for such sales. Management is evaluating other revenue streams, including long-term contracts with industrial and wholesale customers. Management will continue to evaluate the impact of this guidance, including any additional clarifying amendments issued during implementation. Management is finalizing the design and implementation of controls related to the new standard.

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. 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 August 2016, FASB amended the guidance for certain cash flow issues with the objective of reducing existing diversity in practice. This guidance affects the cash flow classification related to certain types of transactions including debt, contingent consideration, proceeds from the settlement of insurance claims, and distributions from equity method investees. The adoption of this guidance is effective for fiscal years beginning after December 15, 2017, including interim periods within those years. This amendment should be applied using a retrospective transition method to each period presented. This guidance will impact the presentation of the cash flow statement, but will not have an impact on the results of operations or financial condition of the Registrants.

In October 2016, FASB amended the income tax guidance related to intra-entity transfers of assets other than inventory. Current GAAP prohibits the recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party. This new guidance states that an entity should recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant 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 flow 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 is

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effective for fiscal years beginning after December 15, 2017, including interim periods within those years. This amendment should be applied using a retrospective transition method to each period presented. This guidance will impact the presentation of the cash flow statement, but will not have an impact on the results of operations or financial condition of the Registrants.

In January 2017, FASB issued amendments to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In January 2017, FASB amended the accounting guidance to simplify the measurement of a goodwill impairment loss. The amended guidance eliminates step two of the goodwill impairment test, which requires a hypothetical purchase price allocation to measure goodwill impairment. Under the new guidance, a goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2019, including interim periods within those years. Early adoption is permitted. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

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. The non-service cost components that are no longer eligible for capitalization under GAAP will be presented as regulatory assets. The adoption of this guidance is effective for annual periods beginning after December 15, 2017, including interim periods within those years. This amendment should be applied retrospectively for the presentation of the service cost in the income statement while the capitalization of the service cost should be applied prospectively. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In May 2017, FASB amended guidance related to service concession arrangements. The amendment clarifies that the grantor, rather than the third-party users, is the customer of the operation services in all cases for service concession arrangements. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In August 2017, FASB amended guidance related to derivatives and hedging. The amendment broadens the financial and non-financial hedging strategies that will be eligible for hedge accounting. The new guidance also

changes how a company tests hedging strategies for effectiveness. 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 does not expect this guidance to have a significant impact 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 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 SEPT. 30, 2017		AT DEC. 31, 2016
Regulatory assets – deferred taxes, net	$	240,431	$	237,449
Mining costs	4,461		6,372
Interest costs	4,590		4,860
AROs	2,590		2,096
Postretirement costs	137,815		145,268
Tree trimming costs	6,801		5,549
Training costs	6,591		6,708
Surcredits, net	3,084		5,876
AMI deferred revenue requirement	4,363		4,772
Emergency declarations	3,976		—
Production operations and maintenance expenses	9,656		13,999
AFUDC equity gross-up	70,046		70,423
Acadia Unit 1 acquisition costs	2,362		2,442
Financing costs	8,385		8,663
Biomass costs	—		18
MISO integration costs	702		1,404
Coughlin transaction costs	976		999
Corporate franchise tax	968		1,308
MATS costs	3,846		4,270
Other	713		710
Total regulatory assets	271,925		285,737
Accumulated deferred fuel	21,057		20,787
Total regulatory assets, net	$	533,413	$	543,973

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

(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Total Cleco Power regulatory assets, net	$	533,413	$	543,973
Cleco Holdings’ Merger adjustments (1)
Fair value of long-term debt	149,256		155,776
Postretirement costs	21,872		23,362
Financing costs	8,708		8,966
Debt issuance costs	6,768		7,606
Total Cleco regulatory assets, net	$	720,017	$	739,683

⁽¹⁾ Cleco Holdings’ regulatory assets include acquisition accounting adjustments as a result

of the Merger.

Emergency Declarations

In August 2016, the LPSC issued emergency declaration executive orders following flooding events in south Louisiana which prohibited public utilities from disconnecting or charging late fees to customers for non-payment in affected parishes. In January 2017, the LPSC issued an order terminating those executive orders effective March 1, 2017. The January 2017 order also provided that public utilities were entitled to formally petition the LPSC to recover lost revenues as a result of the executive orders issued in August 2016. Beginning July 2017, Cleco Power’s lost revenues are being recovered and amortized over a three-year period.

Cleco Holdings’ Merger Adjustments

As a result of the Merger, Cleco implemented acquisition accounting, which eliminated AOCI at the Cleco consolidated level on the date of the Merger. Cleco will continue to recover expenses related to certain postretirement costs; therefore, Cleco recognized a regulatory asset based on its determination that these costs can continue to be collected from customers. These costs are being amortized to Other operations expense over the average remaining service period of participating employees. Cleco will also continue to recover financing costs associated with the settlement of two treasury rate locks and a forward starting swap contract that were previously recognized in AOCI. Additionally, as a result of the Merger, a regulatory asset was recorded for debt issuance costs that were eliminated at Cleco and a regulatory asset was recorded for the difference between the carrying value and the fair value of long-term debt. These regulatory assets are being amortized over the terms of the related debt issuances. On March 1, 2017, Cleco completed the repayment of the first of

two tranches of its Cleco Katrina/Rita storm recovery bonds issued in March 2008. As a result, the fair value adjustments for the redeemed long-term debt and the related unamortized debt issuance cost of $0.7 million on Cleco’s Condensed Consolidated Balance Sheet were derecognized. The offset was to the respective regulatory assets.

Note 5 — Fair Value Accounting

The amounts reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2017, and December 31, 2016, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, short-term debt, and accounts payable approximate fair value because of their short-term nature. Cleco applies the provisions of the fair value measurement standard to its non-recurring, non-financial measurements including business combinations as well as impairment related to goodwill and other long-lived assets.

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

Cleco
	AT SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,743,987	$	2,831,805	$	2,768,149	$	2,754,518

* The carrying value of long-term debt excludes deferred issuance costs of $11.2 million and $11.7 million at September 30, 2017, and December 31, 2016, respectively.

Cleco Power
	AT SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,244,731	$	1,428,761	$	1,262,373	$	1,418,693

* The carrying value of long-term debt excludes deferred issuance costs of $8.6 million and $9.4 million at September 30, 2017, and December 31, 2016, 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:

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Cleco
	CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2017		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2016		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	$	35,117	$	—	$	35,117	$	—	$	66,410	$	—	$	66,410	$	—
FTRs	13,425		—		—		13,425		7,884		—		—		7,884
Total assets	$	48,542	$	—	$	35,117	$	13,425	$	74,294	$	—	$	66,410	$	7,884
Liability description
FTRs	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201
Total liabilities	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201

Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2017		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2016		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	$	33,796	$	—	$	33,796	$	—	$	65,089	$	—	$	65,089	$	—
FTRs	13,425		—		—		13,425		7,884		—		—		7,884
Total assets	$	47,221	$	—	$	33,796	$	13,425	$	72,973	$	—	$	65,089	$	7,884
Liability description
FTRs	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201
Total liabilities	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201

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

Cleco
							SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED SEPT. 30, 2017			FOR THE THREE MONTHS ENDED SEPT. 30, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Beginning balance	$	17,943		$	13,618		$	7,683		$	3,458		$	7,398
Unrealized gains (losses)*	1,591			1,840			(791		)	2,529			(1,031		)
Purchases	419			164			23,537			12,772			2,070
Settlements	(7,066		)	(6,046		)	(17,542		)	(9,183		)	(4,979		)
Ending balance	$	12,887		$	9,576		$	12,887		$	9,576		$	3,458
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet.

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016			2017			2016
Beginning balance	$	17,943		$	13,618		$	7,683		$	7,398
Unrealized gains (losses)*	1,591			1,840			(791		)	1,498
Purchases	419			164			23,537			14,842
Settlements	(7,066		)	(6,046		)	(17,542		)	(14,162		)
Ending balance	$	12,887		$	9,576		$	12,887		$	9,576
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheet.

The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions as of September 30, 2017, and December 31, 2016:

	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW			HIGH
FTRs at Sept. 30, 2017	$	13,425	$	538	RTO auction pricing	FTR price - per MWh	$	(3.07	)	$	5.87
FTRs at Dec. 31, 2016	$	7,884	$	201	RTO auction pricing	FTR price - per MWh	$	(3.61	)	$	6.04

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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 September 30, 2017, 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 $1.8 million, $8.9 million, and $24.4 million, respectively, at September 30, 2017, and $20.0 million, $23.1 million, and $23.3 million, respectively, at December 31, 2016. 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 $0.5 million, $8.9 million, and $24.4 million, respectively, at September 30, 2017, and $18.7 million, $23.1 million, and $23.3 million, respectively, at December 31, 2016. 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 are 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 nine months ended September 30, 2017, and the year ended December 31, 2016, 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 September 30, 2017, and December 31, 2016:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT SEPT. 30, 2017		AT DEC. 31, 2016
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	13,425	$	7,884
Current	Energy risk management liabilities	538		201
Commodity-related contracts, net		$	12,887	$	7,683

The following tables present the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the nine months ended September 30, 2017, and 2016:

Cleco
		AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
								SUCCESSOR						PREDECESSOR
(THOUSANDS)	DERIVATIVES LINE ITEM	FOR THE THREE MONTHS ENDED SEPT. 30, 2017			FOR THE THREE MONTHS ENDED SEPT. 30, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Commodity contracts
FTRs(1)	Electric operations	$	14,062		$	9,718		$	35,172		$	23,467		$	8,563
FTRs(1)	Power purchased for utility customers	(7,767		)	(5,066		)	(18,759		)	(11,742		)	(5,761		)
Total		$	6,295		$	4,652		$	16,413		$	11,725		$	2,802

⁽¹⁾ For the three and nine months ended September 30, 2017, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $1.6 million and $(0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the periods July 1, 2016 - September 30, 2016, January 1, 2016 - April 12, 2016, and April 13, 2016 - September 30, 2016, unrealized (losses) gains associated with FTRs not recognized in income on derivatives of $1.8 million, $(1.0) million, and 2.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

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Cleco Power
		AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	DERIVATIVES LINE ITEM	2017			2016			2017			2016
Commodity contracts
FTRs(1)	Electric operations	$	14,062		$	9,718		$	35,172		$	32,030
FTRs(1)	Power purchased for utility customers	(7,767		)	(5,066		)	(18,759		)	(17,503		)
Total		$	6,295		$	4,652		$	16,413		$	14,527

⁽¹⁾ For the three and nine months ended September 30, 2017, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $1.6 million and $(0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the three and nine months ended September 30, 2016, unrealized gains associated with FTRs not recognized in income on derivatives of $1.8 million and $1.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

At September 30, 2017, and December 31, 2016, Cleco Power had no open positions hedged for natural gas. In June 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. This proposal was submitted to the LPSC on July 28, 2017. An ALJ was assigned to the docket and a status conference was held on October 3, 2017. A procedural schedule was determined and management expects a final determination in the second quarter of 2018.

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 represent rights to congestion credits or charges along a path during a given time frame for a certain MW quantity. FTRs are not designated as hedging instruments for accounting purposes. The total volume of FTRs that Cleco Power had outstanding at September 30, 2017, and December 31, 2016, was 14.4 million MWh and 9.0 million MWh, respectively.

Note 6 — Debt

At September 30, 2017, Cleco and Cleco Power had $6.5 million of short-term debt outstanding under Cleco Power’s $10.0 million uncommitted line of credit, at an all-in interest rate of 2.98%. At December 31, 2016, Cleco and 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 aggregate, to support their working capital needs.

In May 2016, Cleco Holdings completed the private sale of $535.0 million aggregate principal amount of its 3.743% senior notes due May 1, 2026, and $350.0 million aggregate principal amount of its 4.973% senior notes due May 1, 2046. Cleco Holdings used the proceeds from the issuance and sale of these notes to repay a portion of the $1.35 billion Acquisition Loan Facility entered into in connection with the completion of the Merger. On April 28, 2017, Cleco Holdings completed an exchange offer for all of its then outstanding 3.743% and

4.973% senior notes, which were not registered under the Securities Act of 1933, as amended, for an equal principal amount of newly issued 3.743% senior notes due May 1, 2026, and 4.973% senior notes due May 1, 2046, that were so registered. Cleco Holdings did not receive any proceeds from the exchange offer.

On March 1, 2017, Cleco completed the repayment of the first of two tranches of its Cleco Katrina/Rita storm recovery bonds issued in March 2008. The total principal amount for both tranches was $180.6 million. The first tranche had an initial principal amount of $113.0 million at an interest rate of 4.41% and a final maturity date of March 1, 2020. As part of the early redemption on March 1, 2017, Cleco paid $1.1 million in principal and less than $0.1 million in accrued interest.

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 2016 and does not expect to make any in 2017. The required contributions are driven by liability funding target percentages set by law which could cause the required contributions to be uneven among the years. The ultimate amount and timing of the contributions may be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator.

Cleco’s retirees and their dependents may be eligible to receive medical, dental, vision, and life insurance benefits (other benefits). Cleco recognizes the expected cost of these other benefits during the periods in which the benefits are earned.

The components of net periodic pension and other benefit cost for the three and nine months ended September 30, 2017, and 2016 were as follows:

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	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016			2017			2016
Components of periodic benefit costs
Service cost	$	2,260		$	2,229		$	314		$	380
Interest cost	5,412			5,455			372			420
Expected return on plan assets	(6,016		)	(6,001		)	—			—
Amortizations
Prior period service credit	(18		)	(18		)	—			—
Net loss (gain)	2,502			3,365			(32		)	—
Net periodic benefit cost	$	4,140		$	5,030		$	654		$	800

	PENSION BENEFITS									OTHER BENEFITS
	SUCCESSOR						PREDECESSOR			SUCCESSOR					PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
Components of periodic benefit costs
Service cost	$	6,779		$	4,122		$	2,563		$	1,084		$	709	$	431
Interest cost	16,235			10,124			6,242			1,176			784		476
Expected return on plan assets	(18,048		)	(11,195		)	(6,812		)	—			—		—
Amortizations
Prior period service (credit) cost	(53		)	(33		)	(20		)	—			—		34
Net loss (gain)	7,506			5,211			2,798			(37		)	—		181
Net periodic benefit cost	$	12,419		$	8,229		$	4,771		$	2,223		$	1,493	$	1,122

Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three months ended September 30, 2017, and 2016 was $0.5 million and $0.4 million, respectively. The amount for the predecessor period January 1, 2016, through April 12, 2016, was $0.5 million. The expense for the successor periods for the nine months ended September 30, 2017, and April 13, 2016, through September 30, 2016, was $1.4 million and $0.8 million, respectively.

Cleco Holdings is the plan sponsor for the other benefit plans. There are no assets set aside in a trust and the liabilities are reported on the individual subsidiaries’ financial statements. The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2017, was $0.8 million and $2.5 million, respectively. The amounts for the three and nine months ended September 30, 2016, were also $0.8 million and $2.5 million, respectively. The current and non-current portions of the other benefits liability for Cleco and Cleco Power at September 30, 2017, and December 31, 2016, were as follows:

Cleco
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	3,854	$	3,854
Non-current	$	39,296	$	40,196

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	3,345	$	3,345
Non-current	$	34,147	$	34,892

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 current executive officers’ SERP benefits will be 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 year 2016 and will have their annual bonuses set at target rather than actual awards for the year 2017 for the average incentive award portion of their SERP benefit calculation. A third executive officer’s SERP calculation will use a fixed salary amount for 2017 and will exclude any compensation exceeding this amount. 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

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insurance policies. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ death benefits, as well as future SERP payments. However, because SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. All SERP benefits are paid out of the general cash available of the respective companies that employed the officer. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator.

The components of net periodic benefit cost related to SERP for the three and nine months ended September 30, 2017, and 2016, were as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016
Components of periodic benefit costs
Service cost	$	123		$	213
Interest cost	810			839
Amortizations
Prior period service credit	(57		)	(9		)
Net loss	536			511
Total benefit cost	$	1,412		$	1,554

	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Components of periodic benefit costs
Service cost	$	370		$	277		$	702
Interest cost	2,430			1,543			900
Amortizations
Prior period service (credit) cost	(124		)	(42		)	17
Net loss	1,560			1,120			574
Net periodic benefit cost	4,236			2,898			2,193
Curtailment charge	—			—			3,602
Special/contractual termination benefits	315			—			3,222
Total benefit cost	$	4,551		$	2,898		$	9,017

There was a remeasurement of SERP on March 30, 2017, to reflect a special termination benefit resulting from an executive officer’s separation agreement. On the date of the remeasurement, the discount rate decreased from 4.22% to 4.08%. This remeasurement resulted in a special termination benefit for the executive officer of $0.3 million.

There was a remeasurement of SERP at April 13, 2016, to reflect change in control benefits as a result of the Merger. On the date of the remeasurement, the discount rate decreased from 4.60% to 4.15%. This remeasurement resulted in a $3.6 million curtailment charge and $3.2 million of special/contractual termination benefits. The curtailments and special/contractual termination benefits are included in Merger transaction and commitment costs on Cleco’s Consolidated Statements of Income. There was an additional remeasurement of SERP at August 31, 2016, to reflect changes to the plan relating to three executive officers’ SERP benefits being capped as of December 31, 2017, with regard to final compensation. On the date of the remeasurement, the discount rate decreased from 4.15% to 3.47%.

The total expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income was $0.3 million and $0.9 million for the three and nine months ended September 30, 2017, respectively, compared to $0.3

million and $1.1 million for the three and nine months ended September 30, 2016, respectively.

Liabilities relating to SERP are reported on the individual subsidiaries’ financial statements. The current and non-current portions of the SERP liability for Cleco and Cleco Power at September 30, 2017, and December 31, 2016, were as follows:

Cleco
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	4,431	$	4,308
Non-current	$	76,870	$	73,738

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	939	$	885
Non-current	$	15,999	$	15,145

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 nine monthsended September 30, 2017, and 2016, was as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016
401(k) Plan expense	$	1,386	$	1,331

	SUCCESSOR				PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
401(k) Plan expense	$	4,259	$	2,440	$	1,593

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and nine months ended September 30, 2017, and 2016, was as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016
401(k) Plan expense	$	234	$	204

	SUCCESSOR				PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
401(k) Plan expense	$	710	$	378	$	319

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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 nine months ended September 30, 2017, and 2016:

Cleco
					SUCCESSOR				PREDECESSOR
	FOR THE THREE MONTHS ENDED SEPT. 30, 2017		FOR THE THREE MONTHS ENDED SEPT. 30, 2016		FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
Effective tax rate	33.7	%	37.4	%	35.5	%	40.3	%	(704.9	)%

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
	2017		2016		2017		2016
Effective tax rate	35.4	%	35.9	%	36.8	%	19.5	%

For the successor periods, the effective income tax rates for Cleco were different than the federal statutory rate primarily due to permanent tax differences, the flowthrough of state tax benefits, including AFUDC equity, benefits delivered from Cleco’s investment in the NMTC Fund, and state tax expense.

For the predecessor period, the effective income tax rates for Cleco were different than the federal statutory rate primarily due to a significant portion of the merger costs not being deductible, the flowthrough of state tax benefits, including AFUDC equity, benefits delivered from Cleco’s investment in the NMTC Fund, and state tax expense.

For the three and nine months ended September 30, 2017, and 2016, the effective income tax rate for Cleco Power was different than the federal statutory rate primarily due to 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 September 30, 2017, and December 31, 2016, Cleco and Cleco Power had no interest payable related to uncertain tax positions. For the nine months ended September 30, 2017, and 2016, Cleco and Cleco Power had no interest expense related to uncertain tax positions.

At September 30, 2017, Cleco had no liability for uncertain tax positions. Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of September 30, 2017, 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 2013, 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 2017 tax year.

The state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2014 and 2015.

Cleco classifies income tax penalties as a component of other expense. For the nine months ended September 30, 2017, and 2016, no penalties were recognized.

Note 9 — Disclosures about Segments

Cleco’s reportable segment is based on its method of internal reporting, which disaggregates business units by its first-tier subsidiary.

Cleco Power, the reportable segment, engages in business activities from which it earns revenue and incurs expenses. Segment managers report periodically to Cleco’s CEO with discrete financial information and, at least quarterly, present discrete financial information to Cleco and Cleco Power’s Boards of Managers. The reportable segment prepares budgets that are presented to and approved by Cleco and Cleco Power’s Boards of Managers. The column shown as Other in the chart below includes the holding company, a shared services subsidiary, two transmission interconnection facility subsidiaries, and an investment subsidiary.

The financial results of Cleco’s segment 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 SEPT. 30,
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	320,009		$	(2,420	)	$	—		$	317,589
Other operations	20,768			514			—			21,282
Electric customer credits	(372		)	—			—			(372		)
Affiliate revenue	209			13,517			(13,726		)	—
Operating revenue, net	$	340,614		$	11,611		$	(13,726	)	$	338,499
Depreciation and amortization	$	40,049		$	2,179		$	—		$	42,228
Merger transaction and commitment costs	$	—		$	185		$	—		$	185
Interest charges	$	17,141		$	13,331		$	(10	)	$	30,462
Interest income	$	332		$	31		$	(9	)	$	354
Federal and state income tax expense (benefit)	$	30,092		$	(7,038	)	$	—		$	23,054
Net income (loss)	$	54,852		$	(9,548	)	$	—		$	45,304

2016 (THOUSANDS)	CLECO POWER		OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	326,281	$	(2,574	)	$	—		$	323,707
Other operations	18,460		517			(1		)	18,976
Electric customer credits	177		—			—			177
Affiliate revenue	213		13,060			(13,273		)	—
Operating revenue, net	$	345,131	$	11,003		$	(13,274	)	$	342,860
Depreciation and amortization	$	40,353	$	2,182		$	—		$	42,535
Merger transaction and commitment costs	$	—	$	1,869		$	—		$	1,869
Interest charges	$	19,177	$	12,709		$	(28	)	$	31,858
Interest income	$	264	$	82		$	(28	)	$	318
Federal and state income tax expense (benefit)	$	29,427	$	(5,728	)	$	1		$	23,700
Net income (loss)	$	52,572	$	(12,952	)	$	1		$	39,621

SEGMENT INFORMATION FOR THE NINE MONTHS ENDED SEPT. 30,
	SUCCESSOR
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	847,417		$	(8,337	)	$	—		$	839,080
Other operations	58,083			1,544			—			59,627
Electric customer credits	(1,045		)	—			—			(1,045		)
Affiliate revenue	649			41,882			(42,531		)	—
Operating revenue, net	$	905,104		$	35,089		$	(42,531	)	$	897,662
Depreciation and amortization	$	118,280		$	6,351		$	(1	)	$	124,630
Merger transaction and commitment costs	$	—		$	187		$	—		$	187
Interest charges	$	52,654		$	40,297		$	(151	)	$	92,800
Interest income	$	926		$	271		$	(151	)	$	1,046
Federal and state income tax expense (benefit)	$	63,010		$	(20,629	)	$	—		$	42,381
Net income (loss)	$	108,439		$	(31,398	)	$	—		$	77,041
Additions to property, plant, and equipment	$	183,604		$	2,005		$	—		$	185,609
Equity investment in investees (1)	$	18,172		$	—		$	—		$	18,172
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,822,302		$	592,681		$	(17,282	)	$	6,397,701
(1) Balances as of September 30, 2017

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	SUCCESSOR APR. 13, 2016 - SEPT. 30, 2016												PREDECESSOR JAN. 1, 2016 - APR. 12, 2016
2016 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED			CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	558,439		$	(4,805	)	$	—		$	553,634		$	281,154		$	—		$	—		$	281,154
Other operations	32,145			965			—			33,110			18,493			587			—			19,080
Electric customer credits	(381		)	—			—			(381		)	(364		)	—			—			(364		)
Affiliate revenue	406			23,823			(24,229		)	—			263			15,024			(15,287		)	—
Operating revenue, net	$	590,609		$	19,983		$	(24,229	)	$	586,363		$	299,546		$	15,611		$	(15,287	)	$	299,870
Depreciation and amortization	$	71,498		$	5,198		$	(1	)	$	76,695		$	43,698		$	377		$	1		$	44,076
Merger transaction and commitment costs	$	151,501		$	21,671		$	—		$	173,172		$	—		$	34,928		$	(16	)	$	34,912
Interest charges	$	35,937		$	22,430		$	(44	)	$	58,323		$	21,840		$	295		$	(12	)	$	22,123
Interest income	$	382		$	177		$	(44	)	$	515		$	208		$	69		$	(12	)	$	265
Federal and state income tax (benefit) expense	$	(10,028	)	$	(18,474	)	$	—		$	(28,502	)	$	12,993		$	(9,525	)	$	—		$	3,468
Net (loss) income	$	(9,326	)	$	(32,968	)	$	—		$	(42,294	)	$	21,548		$	(25,508	)	$	—		$	(3,960	)
Additions to property, plant, and equipment	$	102,284		$	393		$	—		$	102,677		$	42,353		$	39		$	—		$	42,392
Equity investment in investees (1)	$	18,672		$	—		$	—		$	18,672
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,758,245		$	614,959		$	(30,060	)	$	6,343,144
(1) Balances as of December 31, 2016

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. 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.

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.

On February 13, 2017, $1.2 million of refunds relating to the first complaint were submitted to MISO. As ofSeptember 30, 2017, Cleco Power had$2.0 millionaccrued 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, 2016, Cleco Power filed its monitoring report for the 12-month period ended June 30, 2016, which indicated that no refund was due as a result of the FRP and $0.3 million was due as a result of the cost of service savings from the Merger Commitments. On June 28, 2017, the LPSC approved the 2016 FRP monitoring report which confirmed no earnings-related refund. The $0.3 million cost of service savings were refunded on customer bills in September 2017. 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. As of September 30, 2017, Cleco Power had $1.5 million accrued for the cost of service savings refund.

Merger Commitments

On March 28, 2016, the LPSC approved the Merger. The LPSC’s written order approving the Merger was issued on April 7, 2016. Approval of the Merger was conditioned upon certain commitments, including $136.0 million of customer rate credits. On April 28, 2016, the LPSC voted to issue credits equally to eligible customers with service as of June 30, 2016, beginning in July 2016. As of September 30, 2017, Cleco Power had issued $130.0 million of customer rate credits. Also included in the Merger Commitments were $2.5 million of contributions for economic development for Louisiana state and local organizations to be disbursed over five years, an additional $7.0 million one-time contribution for economic development in Cleco Power’s service territory to be administered by the LED, and $6.0 million of charitable contributions to be disbursed over five years. In December 2016, the $7.0 million one-time contribution was paid to the LED.

In addition, the Merger Commitments included $1.2 million of annual estimated cost of service savings expected as a result of the Merger. The cost of service savings are not subject to the target ROE or any sharing mechanism in the current FRP and will continue until Cleco Power’s anticipated new rates begin on July 1, 2020. The cost of service savings

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are included in the annual monitoring reports and are refunded to customers annually. A report on the status of the Merger Commitments must be filed annually by October 31 for the 12-month period ended June 30. On October 31, 2016, Cleco Power filed the annual Merger Commitment status report for the period ended June 30, 2016. On October 31, 2017, Cleco Power filed the annual Merger Commitment status report for the period ended June 30, 2017. For more information on the cost of service savings, see “— FRP.”

SSR

In September 2016, Cleco Power filed an Attachment Y with MISO requesting retirement of Teche Unit 3 effective April 1, 2017. MISO conducted a study which determined the proposed retirement of Teche Unit 3 would result in violations of specific applicable reliability standards for which no mitigation is available. As a result, MISO designated Teche Unit 3 as an SSR unit until such time that an appropriate alternative solution can be implemented to mitigate reliability issues. One mitigating factor that has been identified is Cleco Power’s Terrebonne to Bayou Vista Transmission project, which is expected to be complete by the third quarter of 2018. Cleco Power has a 12-month SSR Agreement for the period April 1, 2017, to March 31, 2018. During this time, Cleco Power will continue to operate Teche Unit 3. Cleco Power has filed with FERC for its approval to collect $20.3 million annually in SSR payments from MISO which includes 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 Agreement. At the end of the agreement, 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 September 30, 2017, Cleco Power had $2.2 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 next settlement conference is scheduled for November 16, 2017. Cleco Power is unable to determine when a binding FERC order will be issued. Also 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. In the first quarter of 2018, another study is expected to be performed by MISO to determine if an SSR Agreement will be needed after March 31, 2018. 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.

Other

In April 2016, the LPSC issued Docket No. R-34026 to investigate double leveraging issues for all LPSC-jurisdictional utilities whereby double leveraging is utilized to fund a utility’s capital structure, and to consider whether any costs associated with such double leveraging should be included in

the rates paid by the utility’s retail customers. Cleco Power filed a motion to intervene in this proceeding along with other Louisiana utilities. In April 2016, the LPSC also issued Docket No. R-34029 to investigate tax structure issues for all LPSC-jurisdictional utilities to consider whether only the state and federal taxes included in a utility’s retail rate will be those that do not exceed the utility’s share of the actual taxes paid to those federal and state taxing authorities. Cleco Power filed a motion to intervene in this proceeding along with other Louisiana utilities. In October 2016, Cleco received the first set of data requests from the LPSC Staff for each of the above mentioned dockets. Cleco has filed responses to the non-confidential requests and is waiting on the completion of a confidentiality agreement to respond to the confidential requests. Cleco is unable to determine if or when the completion of this confidentiality agreement will occur.

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 September 30, 2017, consisted of its equity investment of $18.2 million. In June 2017, Cleco Power received $0.5 million from Oxbow as a return of investment.

During the first quarter of 2017, the transition from the Dolet Hills mine to the Oxbow mine commenced. This transition was completed in July 2017.

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

INCEPTION TO DATE (THOUSANDS)	AT SEPT. 30, 2017			AT DEC. 31, 2016
Purchase price	$	12,873		$	12,873
Cash contributions	6,399			6,399
Dividends	(1,100		)	(600		)
Total equity investment in investee	$	18,172		$	18,672

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

(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Oxbow’s net assets/liabilities	$	36,344	$	37,345
Cleco Power’s 50% equity	$	18,172	$	18,672
Cleco Power’s maximum exposure to loss	$	18,172	$	18,672

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The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016		2017		2016
Operating revenue	$	392	$	1,034	$	1,997	$	4,661
Operating expenses	392		1,034		1,997		4,661
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 polychlorinated biphenyl (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, 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).

On November 14, 2014, the plaintiff in the Braunstein action moved for a dismissal of the action without prejudice, and that motion was granted on November 19, 2014. On December 3, 2014, the Court consolidated the remaining three actions and appointed interim co-lead counsel. On December 18, 2014, the plaintiffs in the consolidated action filed a Consolidated Amended Verified Derivative and Class Action Petition for Damages and Preliminary and Permanent Injunction (the Consolidated Amended Petition). The consolidated action named Cleco Corporation, its directors, Cleco Partners, and Merger Sub as defendants. The Consolidated Amended Petition alleged, among other things, that Cleco Corporation’s directors breached their fiduciary duties to Cleco’s shareholders and grossly mismanaged Cleco by approving the Merger Agreement because it allegedly did not value Cleco adequately, failing to structure a process through which shareholder value would be maximized, engaging in self-dealing by ignoring conflicts of interest, and failing to disclose material information about the Merger. The Consolidated Amended Petition further alleged that all defendants conspired to commit the breaches of fiduciary duty. Cleco believes that the allegations of the Consolidated Amended Petition are without merit and that it has substantial meritorious defenses to the claims set forth in the Consolidated Amended Petition.

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

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

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

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

Both the Butler and Cashen actions name Cleco Corporation, its directors, Cleco Partners, Merger Sub, MIRA, bcIMC, and John Hancock Financial as defendants. The

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Creative Life Services action names Cleco Corporation, its directors, Cleco Partners, Merger Sub, MIRA, and Macquarie Infrastructure Partners III, L.P., as defendants. On December 11, 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. On December 23, 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. On December 30, 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. On January 23, 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. On February 5, 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.

On February 25, 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 at the Special Meeting of Shareholders held on February 26, 2015, for approval of the Merger Agreement. Following the hearing, the Court denied the plaintiffs’ motion. On June 19, 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 on July 24, 2015.

On March 21, 2016, the plaintiffs filed their Third Consolidated Amended Verified Derivative Petition for Damages and Preliminary and Permanent Injunction. On May 13, 2016, the plaintiffs filed their Fourth Verified Consolidated Amended Class Action Petition. This petition eliminated the request for preliminary and permanent injunction and also named an additional executive officer as a defendant. Cleco filed exceptions seeking dismissal of the amended Petition. A hearing was held on September 15, 2016. On September 26, 2016, the District Court granted the exceptions filed by Cleco and dismissed all claims asserted by the former shareholders. The plaintiffs appealed the District Court’s ruling to the Louisiana Third Circuit Court of Appeal. The Third Circuit Court of Appeal heard oral arguments in the case on September 21, 2017. Cleco expects a ruling by December 31, 2017. 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 for the State of Louisiana. In June 2016, the Third Circuit Court of Appeal for the State of Louisiana 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

On March 17, 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. Management believes that the case, as it relates to Cleco Power, has no merit.

The suit has been removed to federal court in Texas. Unless and until the federal court remands the case, it will stay in federal court.

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

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to pass on to its customers substantially all such charges. Recovery of FAC costs is subject to periodic fuel audits by the LPSC. The LPSC FAC General Order issued in November 1997, in Docket No. U-21497 provides that an audit of FAC filings will be performed at least every other year. In February 2016, the LPSC initiated an audit of Cleco Power’s fuel and purchased power expenses for the period January 2014 through December 2015. The total amount of fuel expense included in the audit was $582.6 million. On January 19, 2017, the LPSC Staff issued its audit report which recommended no disallowance of fuel costs. The report was approved by the LPSC on April 19, 2017. Cleco Power has FAC filings for January 2016 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings.

Environmental Audit

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. 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. In February 2016, the LPSC initiated an audit of Cleco Power’s environmental costs for the period November 2010 through December 2015. The total amount of environmental costs included in the audit was $81.2 million. In December 2016, the LPSC Staff issued its audit report which recommended a disallowance of environmental costs of less than $0.1 million. The report was approved by the LPSC on February 17, 2017. Cleco Power has EAC filings for January 2016 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings.

In the second quarter of 2015, Cleco Power began incurring additional environmental compliance expenses for reagents associated with compliance with 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 24, 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, on April 27, 2017, the court issued an order holding the cases in abeyance pending the EPA’s review of its supplemental finding. Oral arguments are set for November 16, 2017. These expenses are also eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC.

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.

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.

On February 13, 2017, $1.2 million of refunds relating to the first complaint were submitted to MISO. As of September 30, 2017, Cleco Power had $2.0 million accrued for a reduction to the ROE, including accrued interest. 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 September 30, 2017, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters is $4.6 million and has accrued this amount.

Off-Balance Sheet Commitments and Guarantees

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

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

The off-balance sheet commitments are not recognized on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets because management has determined that Cleco and Cleco Power’s affiliates are able to perform the obligations

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under their contracts and that it is not probable that payments by Cleco or Cleco Power will be required.

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

On behalf of Acadia, Cleco Holdings provided guarantees and indemnifications as a result of the sales of Acadia Unit 1 to Cleco Power and Acadia Unit 2 to Entergy Louisiana in 2010 and 2011, respectively. The remaining indemnifications relate to the fundamental organizational structure of Acadia. These remaining indemnifications have no limitations as to time or maximum potential future payments. Currently, 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. Currently, 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 life of the investment, which ends in 2018. The $18.3 million difference between equity contributions and total benefits received will be recognized over the life of the NMTC Fund as net tax benefits are delivered.

Due to the right of offset, the investment and associated debt are presented in Tax credit fund investment, net, on Cleco’s Condensed Consolidated Balance Sheet. At December 31, 2016, the amount of the liability component contained in the net asset was $0.6 million, and it was paid on March 30, 2017. The amount of tax benefits delivered in excess of capital contributions as of September 30, 2017, was $11.8 million.

By using the cost method for investments, the gross investment amortization expense will be recognized over a ten-year period, which is projected to end in 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 October 2007, Cleco Power entered into an agreement with Savage Services that met the accounting definition of a capital lease for barges in order to transport petroleum coke and limestone to Madison Unit 3. In December 2012, Cleco Power entered into an amended agreement for 42 dedicated barges. The amended agreement continued to meet the accounting definition of a capital lease until its expiration on August 31, 2017. Upon expiration of the amended agreement, Cleco Power entered into a second amended agreement with Savage Services to continue use of the 42 barges. The new agreement meets the accounting definition of an operating lease and automatically renews the terms of the lease on a month-to-month basis until terminated by either party. For the three and nine months ended September 30, 2017, Cleco Power recognized $0.3 million in operating lease expense for the barges. Cleco Power is evaluating future options related to its fuel transportation agreement with Savage Services.

Other

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

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Risks and Uncertainties

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

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. On April 7, 2017, Moody’s updated its credit ratings by maintaining Cleco Holdings at Baa3 (stable) and Cleco Power at A3 (stable). On May 30, 2017, S&P affirmed Cleco Holdings’ and Cleco Power’s credit ratings at BBB- (stable) and BBB+ (stable), respectively.

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 Locational Marginal Price (LMP), which includes a component directly related to congestion on the transmission system. Pricing zones with greater transmission congestion may have a higher LMP. Physical transmission constraints present in the MISO market could increase energy costs within Cleco Power’s pricing

zones. Cleco Power uses FTRs to mitigate transmission congestion risk. 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 SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	282	$	526	$	3	$	119
Support Group	1,262		7,767		1,402		7,071
Other (1)	1		—		1		—
Total	$	1,545	$	8,293	$	1,406	$	7,190
(1) Represents Attala and Perryville.

Note 14 — 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 SEPT. 30, 2017								FOR THE NINE MONTHS ENDED SEPT. 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI			POSTRETIREMENT BENFIT NET GAIN (LOSS)			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(631	)	$	—	$	(631	)	$	1,500		$	—	$	1,500
Other comprehensive loss before reclassifications
Postretirement benefit adjustments during the period	—			—		—			(2,065		)	—		(2,065		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net gain	(44		)	—		(44		)	(110		)	—		(110		)
Net current-period other comprehensive loss	(44		)	—		(44		)	(2,175		)	—		(2,175		)
Balances, Sept. 30, 2017	$	(675	)	$	—	$	(675	)	$	(675	)	$	—	$	(675	)

	FOR THE THREE MONTHS ENDED SEPT. 30, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	—		$	—	$	—
Other comprehensive loss before reclassifications
Postretirement benefits adjustment during the period	(2,308		)	—		(2,308		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	3			—		3
Net current-period other comprehensive loss	(2,305		)	—		(2,305		)
Balances, Sept. 30, 2016	$	(2,305	)	$	—	$	(2,305	)

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	FOR THE NINE MONTHS ENDED SEPT. 30, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
PREDECESSOR
Balances, beginning of period	$	(20,857	)	$	(5,728	)	$	(26,585	)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	587			—			587
Reclassification of net loss to interest charges	—			60			60
Net current-period other comprehensive income	587			60			647
Balances, Apr. 12, 2016	$	(20,270	)	$	(5,668	)	$	(25,938	)
SUCCESSOR(1)
Balances, Apr. 13, 2016	$	—		$	—		$	—
Other comprehensive loss before reclassifications
Postretirement benefits adjustment during the period	(2,308		)	—			(2,308		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	3			—			3
Net current-period other comprehensive loss	(2,305		)	—			(2,305		)
Balances, Sept. 30, 2016	$	(2,305	)	$	—		$	(2,305	)
(1) As a result of the Merger, accumulated other comprehensive income was reduced to zero on April 13, 2016, as required by acquisition accounting.

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30, 2017									FOR THE NINE MONTHS ENDED SEPT. 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	$	(8,132	)	$	(5,411	)	$	(13,543	)	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive loss before reclassifications
Postretirement benefit adjustments during the period	—			—			—			(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	167			—			167			524			—			524
Reclassification of net loss to interest charges	—			53			53			—			159			159
Net current-period other comprehensive income (loss)	167			53			220			(60		)	159			99
Balances, Sept. 30, 2017	$	(7,965	)	$	(5,358	)	$	(13,323	)	$	(7,965	)	$	(5,358	)	$	(13,323	)

	FOR THE THREE MONTHS ENDED SEPT. 30, 2016									FOR THE NINE MONTHS ENDED SEPT. 30, 2016
(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	$	(10,983	)	$	(5,622	)	$	(16,605	)	$	(11,364	)	$	(5,728	)	$	(17,092	)
Other comprehensive income before reclassifications:
Postretirement benefit adjustments during the period	2,013			—			2,013			2,013			—			2,013
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	167			—			167			548			—			548
Reclassification of net loss to interest charges	—			53			53			—			159			159
Net current-period other comprehensive income	2,180			53			2,233			2,561			159			2,720
Balances, Sept. 30, 2016	$	(8,803	)	$	(5,569	)	$	(14,372	)	$	(8,803	)	$	(5,569	)	$	(14,372	)

Note 15 — Subsequent Event

On October 10, 2017, Cleco Power, Attala, Perryville, Entergy Louisiana, and Entergy Mississippi completed a joint filing with FERC. The filing requested approval for Cleco Power and Perryville to sell certain transmission assets to Entergy Louisiana and for Attala to sell certain transmission assets to Entergy Mississippi. The filing requested an approval date by December 18, 2017. If approved, the parties will enter into binding agreements for the sale of the assets. The parties expect completion of the agreements by the end of 2017.

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

Cleco uses its website, https://www.cleco.com, as a routine channel for distribution of important information, including news releases and financial information. Cleco’s website is the primary source of publicly disclosed news about Cleco. Cleco is providing the address to its website solely for informational purposes and does not intend for the address to be an active link. The contents of the website are not incorporated into this 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, 2016, 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 nine months ended September 30, 2017, and 2016.

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 288,000 customers in Louisiana through its retail business and supplies wholesale power in Louisiana and Mississippi.

Merger

On April 13, 2016, Cleco Holdings completed its merger with Merger Sub whereby Merger Sub 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, as a direct, wholly owned subsidiary of Cleco Group and an indirect, wholly owned subsidiary of Cleco Partners. For more information on the Merger, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 2 — Business Combinations.”

Enterprise Business Applications Project

The Enterprise Business Applications 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. Management expects the project to be complete by the third quarter of 2019. The total estimated project cost is $130.0 million. As of September 30, 2017, Cleco had spent $18.3 million on the project.

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 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 Cenla Transmission Expansion project and the St. Mary Clean Energy Center project; initiating construction of the Terrebonne to Bayou Vista Transmission project and the Coughlin Pipeline project; and maintaining and growing its wholesale and retail business. These initiatives are discussed below.

Cenla Transmission Expansion Project

The Cenla Transmission Expansion project includes the construction of transmission lines and a transmission substation within the central Louisiana area. The project is expected to improve reliability to customers by relieving forecasted overloads and mitigating potential load shedding events while providing flexibility to allow routine maintenance outages and serve future growth in the central Louisiana area. The substation construction is complete and has been placed in service. New line construction is complete and the re-conductor portion of the project is in progress. The project is expected to be complete by the end of 2017 with an estimated cost of $31.4 million. As of September 30, 2017, Cleco Power had spent $29.5 million on the project.

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 by the third quarter of 2018 at an estimated cost of $99.8 million. The project is expected to generate more than 300,000 MWh of zero additional carbon emitting energy each year. As of September 30, 2017, Cleco Power had spent $62.6 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. The project team is finalizing negotiations on the right-of-way and land acquisition agreements. Cleco Power’s portion of the joint project with Entergy Louisiana is expected to cost $48.0 million. Construction is expected to be complete by the fourth quarter of 2018. As of September 30, 2017, Cleco Power had spent $6.5 million on the project.

Coughlin Pipeline Project

The Coughlin Pipeline project includes construction of a pipeline directly connecting the Pine Prairie Energy Center to

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Cleco’s Coughlin Power Station. The project is expected to increase reliability for fuel delivery and mitigate exposure to transportation cost increases. On June 28, 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 its next rate case. The project is expected to be complete in the second quarter of 2019 with an estimated cost of $29.4 million. As of September 30, 2017, Cleco Power had spent $0.2 million on the project.

Other

Cleco Power is working on securing 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

All of Cleco’s financial information for the nine months ended September 30, 2017, and 2016 is presented such that pre-merger activity is shown as “Predecessor” and post-merger activity is shown as “Successor.” The purchase price of the Merger was allocated to the related assets and liabilities based on their respective estimated fair values on the Merger date, with the remaining consideration recorded as goodwill. The fair values of assets are being amortized over their estimated useful lives in a manner that best reflects the economic benefits derived from such assets. Goodwill is not amortized, but is subject to impairment testing, annually, during the third quarter. Such adjustments to fair value and the allocation of purchase price between identifiable intangibles and goodwill will have an impact on Cleco’s expenses and profitability. For more information on Goodwill, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Polices — Goodwill.”

Comparison of the Three Months Ended September 30, 2017, and 2016

Cleco
	FOR THE THREE MONTHS ENDED SEPT. 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2017		2016		VARIANCE			CHANGE
Operating revenue, net	$	338,499	$	342,860	$	(4,361	)	(1.3	)%
Operating expenses	243,387		249,717		6,330			2.5	%
Operating income	$	95,112	$	93,143	$	1,969		2.1	%
Allowance for equity funds used during construction	$	2,096	$	1,308	$	788		60.2	%
Other income, net	$	1,258	$	410	$	848		206.8	%
Interest charges	$	30,462	$	31,858	$	1,396		4.4	%
Federal and state income tax expense	$	23,054	$	23,700	$	646		2.7	%
Net income	$	45,304	$	39,621	$	5,683		14.3	%

Operating revenue, net decreased $4.4 million during the third quarter of 2017 compared to the third quarter of 2016 primarily due to lower base revenue partially offset by higher

fuel cost recovery revenue and higher other operations revenue at Cleco Power.

Operating expenses decreased $6.3 million during the third quarter of 2017 compared to the third quarter of 2016primarily due to lower other operations expenses at Cleco Power, lower merger transaction and commitment costs at Cleco Holdings, and lower maintenance expenses at Cleco Power. These decreases were partially offset by higher recoverable fuel and power purchased at Cleco Power.

Other income, net increased $0.8 million during the third quarter of 2017 compared to the third quarter of 2016 primarily due to the increase in the cash surrender value of life insurance policies at Cleco Holdings due to favorable market conditions, higher mutual assistance income at Cleco Power, and higher royalty income at Cleco Power. These increases were partially offset by the absence of a death benefit recognized on life insurance policies and higher mutual assistance expenses at Cleco Power.

Interest charges decreased $1.4 million during the third quarter of 2017 compared to the third quarter of 2016 primarily due to long-term debt redeemed and replaced with lower interest rate debt in the fourth quarter of 2016 at Cleco Power, partially offset by higher interest rates on Cleco Holdings’ $300.0 million long-term variable rate bank term loan.

Federal and state income tax expense decreased $0.6 million during the third quarter of 2017 compared to the third quarter of 2016 primarily due to $4.4 million to record tax expense at the consolidated projected annual effective tax rate and $1.3 million for adjustments for permanent tax differences. These decreases were partially offset by $2.6 million for the flowthrough of state tax benefits, $2.2 million for the change in pretax income, excluding AFUDC equity, and $0.3 million for miscellaneous tax items. The effective income tax rate for the third quarter of 2017 and 2016 was 33.7% and 37.4%, respectively. The estimated annual effective income tax rate used during the third quarter of 2017 and 2016 for Cleco might not be indicative of the full-year income tax rate.

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

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Cleco Power
				FOR THE THREE MONTHS ENDED SEPT. 30,
						FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2017			2016			VARIANCE			CHANGE
Operating revenue
Base	$	187,149		$	198,448		$	(11,299	)	(5.7	)%
Fuel cost recovery	132,860			127,833			5,027			3.9	%
Electric customer credits	(372		)	177			(549		)	(310.2	)%
Other operations	20,768			18,460			2,308			12.5	%
Affiliate revenue	209			213			(4		)	(1.9	)%
Operating revenue, net	340,614			345,131			(4,517		)	(1.3	)%
Operating expenses
Recoverable fuel and power purchased	132,866			127,834			(5,032		)	(3.9	)%
Non-recoverable fuel and power purchased	9,706			10,132			426			4.2	%
Other operations	28,680			35,886			7,206			20.1	%
Maintenance	17,812			19,326			1,514			7.8	%
Depreciation and amortization	40,049			40,353			304			0.8	%
Taxes other than income taxes	12,008			12,180			172			1.4	%
Total operating expenses	241,121			245,711			4,590			1.9	%
Operating income	$	99,493		$	99,420		$	73		0.1	%
Allowance for equity funds used during construction	$	2,096		$	1,308		$	788		60.2	%
Interest charges	$	17,141		$	19,177		$	2,036		10.6	%
Federal and state income tax expense	$	30,092		$	29,427		$	(665	)	(2.3	)%
Net income	$	54,852		$	52,572		$	2,280		4.3	%

Cleco Power’s net income in the third quarter of 2017 increased $2.3 million compared to the third quarter of 2016 primarily as a result of the following factors:

• lower other operations expense,

• higher other operations revenue,

• lower interest charges, and

• lower maintenance expense.

These increases were partially offset by lower base 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 SEPT. 30,
(MILLION kWh)	2017	2016	FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	1,113	1,225		(9.1	)%
Commercial	771	813		(5.2	)%
Industrial	535	504		6.2	%
Other retail	35	35		—	%
Total retail	2,454	2,577		(4.8	)%
Sales for resale	924	949		(2.6	)%
Total retail and wholesale customer sales	3,378	3,526		(4.2	)%

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

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	92,782	$	100,775		(7.9	)%
Commercial	49,848		52,082			(4.3	)%
Industrial	21,690		21,215			2.2	%
Other retail	2,732		2,812			(2.8	)%
Surcharge	5,507		6,080			(9.4	)%
Total retail	172,559		182,964			(5.7	)%
Sales for resale	14,590		15,484			(5.8	)%
Total base revenue	$	187,149	$	198,448		(5.7	)%

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.

	FOR THE THREE MONTHS ENDED SEPT. 30,
				2017 CHANGE
	2017	2016	NORMAL	PRIOR YEAR		NORMAL
Cooling degree-days	1,519	1,744	1,511	(12.9	)%	0.5	%

Base

Base revenue decreased $11.3 millionduring the third quarter of 2017 compared to the third quarter of 2016 due to $9.2 million of lower usage as a result of milder summer weather and lower sales to wholesale customers, $1.9 million due to lower rates to a site specific industrial customer, $0.7 million due to lower revenue related to MATS, and $0.2 million of lower other revenue. These decreases were partially offset by $0.7 million due to an annual rate adjustment that began on July 1, 2017.

Cleco Power expects increased base revenue of $8.0 million in 2018 and an additional $8.6 million in 2019 through an FRP rider associated with the recovery of expenditures for capital projects. 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, 2016.

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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 75% of Cleco Power’s total fuel cost during the third quarter of 2017 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 powerexpenses 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. 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.”

Other Operations Revenue

Other operations revenue increased $2.3 million during the third quarter of 2017 compared to the third quarter of 2016primarily due to $2.2 million of higher forfeited discounts and reconnect fees mostly due to the absence of the 2016 customer rate credits as a result of the Merger and the absence of LPSC executive orders relating to 2016 flooding, $1.2 million of generation revenue from SSR payments, and $0.2 million of higher miscellaneous other operations revenue. These increases were partially offset by $1.3 million of lower net transmission revenue. For more information on the SSR, see “Financial Condition — Regulatory and Other Matters — Retail Rates of Cleco Power — SSR.”

Non-recoverable Fuel and Power Purchased

Non-recoverable fuel and power purchased decreased $0.4 million during the third quarter of 2017 compared to the third quarter of 2016 primarily due to $1.9 million of lower net MISO transmission expenses due to lower usage and rates and $0.3 million due to the absence of a reserve for uncollectible transmission expenses. These decreases were partially offset by $0.8 million of higher miscellaneous expenses, $0.6 million of MISO SSR transmission expenses, and $0.4 million of expenses related to flood damages. For more information on the SSR, see “Financial Condition — Regulatory and Other Matters — Retail Rates of Cleco Power — SSR.”

Other Operations Expense

Other operations expense decreased $7.2 million during the third quarter of 2017 compared to the third quarter of 2016primarily due to $2.1 million of higher capitalized administrative and general expenses, $1.3 million of lower salaries, $1.1 million of lower fees for outside services, $1.1 million of flood related uncollectible accounts deferred to regulatory assets, $0.7 million of lower employee benefit expenses, $0.5 million of higher administrative and general costs billed to joint owners, and $0.5 million of lower generation operations expenses. These decreases were partially offset by $0.1 million of higher miscellaneous other operations expenses.

Maintenance

Maintenance expense decreased $1.5 million during the third quarter of 2017 compared to the third quarter of 2016 primarily due to $1.2 million of lower net generating station routine maintenance expenses, $0.2 million of lower distribution

routine maintenance expenses, and $0.1 million of lower administrative and general maintenance expenses.

Allowance for Equity Funds Used During Construction

Allowance for equity funds used during construction increased $0.8 million during the third quarter of 2017 compared to the third quarter of 2016 primarily due to higher costs related to the St. Mary Clean Energy Center project and other capital projects.

Interest Charges

Interest charges decreased $2.0 million during the third quarter of 2017 compared to the third quarter of 2016 due to long-term debt redeemed and replaced with lower interest rate debt in the fourth quarter of 2016.

Income Taxes

Federal and state income tax expense increased $0.7 million during the third quarter of 2017 compared to the third quarter of 2016 primarily due to $2.6 million for the flowthrough of state tax benefits, $1.4 million for the change in pretax income, excluding AFUDC equity, and $1.1 million for tax returns as filed. These increases were partially offset by $4.4 million to record tax expense at the projected annual effective tax rate.

The effective income tax rate for the third quarter of 2017 and 2016 was 35.4% and 35.9%, respectively. The estimated annual effective income tax rate used during the third quarter of 2017 and 2016 for Cleco Power might not be indicative of the full-year income tax rate.

Comparison of the Nine Months Ended September 30, 2017, and 2016

Cleco
	SUCCESSOR					PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Operating revenue, net	$	897,662	$	586,363		$	299,870
Operating expenses	693,501		603,368			279,507
Operating income (loss)	$	204,161	$	(17,005	)	$	20,363
Interest income	$	1,046	$	515		$	265
Allowance for equity funds used during construction	$	4,446	$	2,057		$	723
Other income, net	$	2,569	$	1,960		$	280
Interest charges	$	92,800	$	58,323		$	22,123
Federal and state income tax expense (benefit)	$	42,381	$	(28,502	)	$	3,468
Net income (loss)	$	77,041	$	(42,294	)	$	(3,960	)

Cleco’s net income attributable to the successor period for the nine months ended September 30, 2017, was $77.0 million. There were no significant changes in the underlying trends impacting net income. The effective income tax rate for the period was 35.5%.

Cleco’s net loss attributable to the successor period April 13, 2016, through September 30, 2016, was $42.3 million. There were no significant changes in the underlying trends impacting net loss with the exception of the change in pretax loss primarily related to:

• $173.2 million of merger transaction and commitment costs,

• $21.6 million of interest costs related to debt obtained as a result of the Merger,

• $4.8 million of an offset to operating revenue related to the amortization of the intangible asset recorded for the fair

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value adjustment of wholesale power supply agreements as a result of the Merger, and

• $4.6 million of amortization of the fair value adjustment made as a result of the Merger to record the stepped-up basis for the Coughlin assets.

The effective income tax rate for the period was 40.3%.

Cleco’s net loss attributable to the predecessor period January 1, 2016, through April 12, 2016, was $4.0 million. There were no significant changes in the underlying trends impacting net loss with the exception of the change in pretax loss primarily related to $34.9 million of merger transaction costs.The effective income tax rate for the period was (704.9)%.

The estimated annual effective income tax rate used during the nine months ended September 30, 2017, and 2016 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 NINE MONTHS ENDED SEPT. 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2017			2016			VARIANCE			CHANGE
Operating revenue
Base	$	498,417		$	515,294		$	(16,877	)	(3.3	)%
Fuel cost recovery	349,000			324,299			24,701			7.6	%
Electric customer credits	(1,045		)	(745		)	(300		)	(40.3	)%
Other operations	58,083			50,638			7,445			14.7	%
Affiliate revenue	649			669			(20		)	(3.0	)%
Operating revenue, net	905,104			890,155			14,949			1.7	%
Operating expenses
Recoverable fuel and power purchased	348,853			324,305			(24,548		)	(7.6	)%
Non-recoverable fuel and power purchased	26,885			27,920			1,035			3.7	%
Other operations	90,453			94,566			4,113			4.3	%
Maintenance	66,496			71,818			5,322			7.4	%
Depreciation and amortization	118,280			115,196			(3,084		)	(2.7	)%
Taxes other than income taxes	35,412			36,096			684			1.9	%
Merger commitment costs	—			151,501			151,501			100.0	%
Gain on sale of asset	—			(1,095		)	(1,095		)	(100.0	)%
Total operating expenses	686,379			820,307			133,928			16.3	%
Operating income	$	218,725		$	69,848		$	148,877		213.1	%
Allowance for equity funds used during construction	$	4,446		$	2,780		$	1,666		59.9	%
Other income (expense), net	$	6		$	(254	)	$	260		102.4	%
Interest charges	$	52,654		$	57,777		$	5,123		8.9	%
Federal and state income tax expense	$	63,010		$	2,965		$	(60,045	)	*
Net income	$	108,439		$	12,222		$	96,217		787.2	%
* Not meaningful

Cleco Power’s net income in the first nine months of 2017 increased $96.2 million compared to the first nine months of 2016 primarily as a result of the following factors:

• the absence of merger commitment costs,

• higher other operations revenue,

• lower maintenance expense,

• lower interest charges,

• lower other operations expense,

• higher allowance for equity funds used during construction, and

• lower non-recoverable fuel and power purchased.

These increases were partially offset by:

• higher income taxes,

• lower base revenue,

• higher depreciation and amortization, and

• the absence of a gain on sale of asset.

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

	FOR THE NINE MONTHS ENDED SEPT. 30,
(Million kWh)	2017	2016	FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	2,692	2,920		(7.8	)%
Commercial	2,026	2,110		(4.0	)%
Industrial	1,529	1,471		3.9	%
Other retail	99	103		(3.9	)%
Total retail	6,346	6,604		(3.9	)%
Sales for resale	2,256	2,385		(5.4	)%
Total retail and wholesale customer sales	8,602	8,989		(4.3	)%

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

	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	221,689	$	232,430		(4.6	)%
Commercial	143,549		147,837			(2.9	)%
Industrial	64,778		64,395			0.6	%
Other retail	7,980		8,189			(2.6	)%
Surcharge	16,241		16,771			(3.2	)%
Total retail	454,237		469,622			(3.3	)%
Sales for resale	44,180		45,672			(3.3	)%
Total base revenue	$	498,417	$	515,294		(3.3	)%

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 NINE MONTHS ENDED SEPT. 30,
				2017 CHANGE
	2017	2016	NORMAL	PRIOR YEAR		NORMAL
Heating degree-days	440	755	942	(41.7	)%	(53.3	)%
Cooling degree-days	2,675	2,885	2,531	(7.3	)%	5.7	%

Base

Base revenue decreased $16.9 million during the first nine months of 2017 compared to the first nine months of 2016 primarily due to $13.9 million of lower usage as a result of milder weather and lower sales to wholesale customers, $4.0 million due to lower rates to a site specific industrial customer,

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and $0.1 million of lower other revenue. These decreases were partially offset by $1.0 million for annual rate adjustments and $0.1 million due to higher revenue related to MATS.

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, 2016.

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 nine months of 2017 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. 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.”

Other Operations Revenue

Other operations revenue increased $7.4 million during the first nine months of 2017 compared to the first nine months of 2016 primarily related to $6.3 million of generation revenue from SSR payments, $2.0 million of higher forfeited discounts and reconnect fees mostly due to the absence of the 2016 customer rate credits as a result of the Merger and the absence of LPSC executive orders relating to 2016 flooding, $1.0 million of higher net transmission revenue, and $0.4 million of higher miscellaneous revenue. These increases were partially offset by $2.3 million of lower transmission revenue from wholesale customers as a result of issuing customer credits relating to the MISO ROE complaints. For more information on the SSR, see “Financial Condition — Regulatory and Other Matters — Retail Rates of Cleco Power — SSR.”

Non-recoverable Fuel and Power Purchased

Non-recoverable fuel and power purchased decreased $1.0 million during the first nine months of 2017 compared to the first nine months of 2016 primarily due to a $2.3 million refund from MISO for wholesale customers relating to the MISO ROE complaints, $1.6 million for the absence of a reserve for uncollectible transmission expenses, and $1.3 million due to the absence of expenses related to fuel accounting software. These decreases were partially offset by $2.7 million of MISO SSR transmission expenses, $0.8 million of higher miscellaneous expenses, $0.4 million of expenses related to flood damages, and $0.3 million of higher net MISO transmission expenses due to higher usage and rates. For more information on the SSR, see “Financial Condition — Regulatory and Other Matters — Retail Rates of Cleco Power — SSR.”

Other Operations Expense

Other operations expense decreased $4.1 million during the first nine months of 2017 compared to the first nine months of 2016 primarily due to $2.1 million of higher capitalized

administrative and general expenses, $1.4 million of lower salaries, $1.1 million of the flood related uncollectible accounts deferred to regulatory assets, $1.1 million of lower generation operations expenses, $0.7 million of lower employee benefits expenses, and $0.7 million of higher company use of electricity. These decreases were partially offset by $1.3 million of higher fees for outside services, $0.9 million for higher uncollectible accounts, and $0.8 million of higher customer service expenses.

Maintenance Expense

Maintenance expense decreased $5.3 million during the first nine months of 2017 compared to the first nine months of 2016 primarily due to $4.7 million of lower net generating station outage and routine maintenance expenses and $1.0 million of lower transmission and distribution routine maintenance expenses. These decreases were partially offset by $0.4 million of higher administrative and general maintenance expenses.

Depreciation and Amortization

Depreciation and amortization expense increased $3.1 million during the first nine months of 2017 compared to the first nine months of 2016 primarily due to $3.6 million of normal recurring additions to fixed assets and $1.8 million of lower deferrals of corporate franchise taxes to regulatory assets. These increases were partially offset by $1.7 million due to the absence of amortization related to transition assets, $0.5 million of lower amortization of intangible assets, and $0.1 million of lower miscellaneous amortization.

Merger Commitment Costs

Merger commitment costs decreased $151.5 million during the first nine months of 2017 compared to the first nine months of 2016 due to the close of the Merger in April 2016.

Allowance for Equity Funds Used During Construction

Allowance for equity funds used during construction increased $1.7 million during the first nine months of 2017 compared to the first nine months of 2016 primarily due to higher costs related to the St. Mary Clean Energy Center project and other capital projects.

Other Income (Expense), Net

Other income, net increased $0.3 million during the first nine months of 2017 compared to the first nine months of 2016 primarily due to $0.9 million of higher mutual assistance income, $0.3 million of higher royalty income, $0.3 million due to the absence of a decrease in cash surrender value of life insurance policies, and $0.1 million due to lower miscellaneous expenses. These increases were partially offset by $0.9 million of higher mutual assistance expenses and $0.4 million due to the absence of a death benefit recognized on life insurance policies.

Interest Charges

Interest charges decreased $5.1 million during the first nine months of 2017 compared to the first nine months of 2016 primarily due to long-term debt redeemed and replaced with lower interest rate debt in the fourth quarter of 2016.

Income Taxes

Federal and state income tax expense increased $60.0 million during the first nine months of 2017 compared to the first nine

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months of 2016 primarily due to $60.3 million for the change in pretax income, excluding AFUDC equity, $1.2 million to record tax expense at the projected annual effective tax rate, and $1.1 million for tax returns as filed. These increases were partially offset by $2.5 million for the flowthrough of state tax benefits and $0.1 million for miscellaneous tax items.

The effective income tax rate for the nine months ended September 30, 2017, and 2016 was 36.8% and 19.5%, respectively. The estimated annual effective income tax rate used during the first nine months of 2017 and 2016 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 September 30, 2017:

	SENIOR UNSECURED DEBT		CORPORATE CREDIT
	MOODY’S	S&P	S&P
Cleco Holdings	Baa3	BBB-	BBB-
Cleco Power	A3	BBB+	BBB+

On April 7, 2017, Moody’s updated its credit ratings by maintaining Cleco Holdings at Baa3 (stable) and Cleco Power at A3 (stable). On May 30, 2017, S&P affirmed Cleco Holdings’ and Cleco Power’s credit ratings at BBB- (stable) and BBB+ (stable), respectively.

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 by S&P or Moody’s, Cleco Holdings and/or Cleco Power would be required to pay additional fees and incur higher interest rates for borrowings under their respective credit facilities.

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 required Cleco Power to provide credit support which may increase or decrease due to the timing of the settlement schedules. At September 30, 2017, 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, 2016.

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.

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 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.”

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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.

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

Cleco
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,798	$	9,213
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	3,876		12,671
Total current	8,874		23,084
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	17,999		17,379
Cleco Power’s charitable contributions	3,640		4,179
Cleco Power’s rate credit escrow	2,887		1,831
Total non-current	24,547		23,410
Total restricted cash and cash equivalents	$	33,421	$	46,494

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,798	$	9,213
Charitable contributions	1,200		1,200
Rate credit escrow	3,876		12,671
Total current	8,874		23,084
Non-current
Future storm restoration costs	17,999		17,379
Charitable contributions	3,640		4,179
Rate credit escrow	2,887		1,831
Total non-current	24,526		23,389
Total restricted cash and cash equivalents	$	33,400	$	46,473

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, 2016, to September 30, 2017, was due to Cleco Katrina/Rita using $17.9 million for scheduled storm recovery bond principal payments and $3.6 million for related interest payments, partially offset by collections of $16.1 million net of administration fees.

Included in the Merger Commitments were $6.0 million of charitable contributions to be disbursed over five years and $136.0 million of rate credits to eligible customers. In April 2016, in accordance with the Merger Commitments, Cleco Power established the charitable contribution fund and deposited the rate credit funds into an escrow account. In April 2016, the LPSC voted to issue the rate credits equally to customers with service as of June 30, 2016, beginning in July 2016. As of September 30, 2017, $1.2 million of the charitable contributions and $129.4 million of the rate credits had been released from restricted cash.

Debt

Cleco Consolidated

At September 30, 2017, Cleco had $6.5 million of short-term debt outstanding on Cleco Power’s $10.0 million uncommitted line of credit, at an all-in interest rate of 2.98%. Cleco had no short-term debt outstanding at December 31, 2016. 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 aggregate, to support their working capital needs.

At September 30, 2017, Cleco’s long-term debt outstanding was $2.73 billion, of which $19.2 million was due within one year. The long-term debt due within one year at September 30, 2017, represents principal payments for the Cleco Katrina/Rita storm recovery bonds. For Cleco, long-term debt decreased$25.5 million from December 31, 2016, primarily due to $17.9 million of scheduled payments made on Cleco Katrina/Rita storm recovery bonds, $6.5 million for amortizations of long-term debt fair value adjustments related to the Merger, and a $1.8 million decrease in capital lease obligations. These decreases were partially offset by $0.7 million of debt issuance cost and debt discount amortizations.

In May 2016, Cleco Holdings completed the private sale of $535.0 million aggregate principal amount of its 3.743% senior notes due May 1, 2026, and $350.0 million aggregate principal amount of its 4.973% senior notes due May 1, 2046. Cleco Holdings used the proceeds from the issuance and sale of these notes to repay a portion of the $1.35 billion Acquisition Loan Facility entered into in connection with the completion of the Merger. On April 28, 2017, Cleco Holdings completed an exchange offer for all of its then outstanding 3.743% and 4.973% senior notes, which were not registered under the Securities Act of 1933, as amended, for an equal principal amount of newly issued 3.743% senior notes due May 1, 2026, and 4.973% senior notes due May 1, 2046, that were so registered. Cleco Holdings did not receive any proceeds from the exchange offer.

On March 1, 2017, Cleco completed the repayment of the first of two tranches of its Cleco Katrina/Rita storm recovery bonds issued in March 2008. For more information, see “—- Cleco Power” below.

Cash and cash equivalents available at September 30, 2017, were $6.1 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 $406.1 million.

At September 30, 2017, 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 September 30, 2017, and December 31, 2016, Cleco had a working capital surplus of $162.3 million and $174.9 million, respectively. The $12.6 milliondecrease in working capital is primarily due to:

• a $23.9 increase in interest accrued primarily due to timing of interest payments,

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• a $22.9 million increase in taxes payable primarily due to timing of property tax payments, partially offset by lower income taxes,

• a $17.0 million decrease in cash and cash equivalents,

• a $14.2 million decrease in restricted cash and cash equivalents,

• a $6.5 million increase in short-term debt primarily due to outstanding borrowings on Cleco Power’s uncommitted line of credit, and

• a $6.5 million increase in other current liabilities primarily due to accruals for SSR payments received for capital expenditures, and timing of benefits and incentives.

These decreases in working capital were partially offset by:

• a $26.2 million increase in customer accounts receivable and unbilled revenue primarily due to the normal seasonal fluctuations in retail revenue, timing of receipts from a wholesale customer and additional deferred arrangements due to the LPSC executive orders,

• a $21.0 million decrease in accounts payable primarily due to the timing of property tax and vendor payments,

• a $14.2 million increase in other accounts receivable primarily due to higher receivables for a lignite fuel credit, an insurance reimbursement, SSR payments, and timing of pole attachment receivables,

• a $9.4 million decrease in provision for merger commitments primarily due to the issuance of Merger rate credits, and

• a $5.4 million increase in fuel inventory primarily due to higher petroleum coke and limestone due to lower plant operations and higher coal purchases, partially offset by lower lignite purchases.

Cleco Holdings (Holding Company Level)

Cleco Holdings had no short-term debt outstanding at September 30, 2017, and December 31, 2016. 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 aggregate, to support their working capital needs.

Cash and cash equivalents available at September 30, 2017, were $1.8 million, combined with the $100.0 million credit facility capacity for total liquidity of $101.8 million.

Cleco Power

At September 30, 2017, Cleco Power had $6.5 million of short-term debt outstanding on an uncommitted line of credit at an all-in interest rate of 2.98%. Cleco Power had no short-term debt outstanding at December 31, 2016. 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 aggregate, to support their working capital needs.

At September 30, 2017, Cleco Power’s long-term debt outstanding was $1.24 billion, of which $19.2 million was due within one year. The long-term debt due within one year at September 30, 2017, represents principal payments for the Cleco Katrina/Rita storm recovery bonds. For Cleco Power, long-term debt decreased$18.6 million from December 31, 2016, primarily due to $17.9 million of scheduled payments made on Cleco Katrina/Rita storm recovery bonds and a $1.8 million decrease in capital lease obligations. These decreases

were partially offset by $1.1 million of debt issuance cost and debt discount amortizations.

On March 1, 2017, Cleco Power completed the repayment of the first of two tranches of its Cleco Katrina/Rita storm recovery bonds issued in March 2008. The total principal amount for both tranches was $180.6 million. The first tranche had an initial principal amount of $113.0 million at an interest rate of 4.41%, and a final maturity date of March 1, 2020. As part of the early redemption on March 1, 2017, Cleco Power paid $1.1 million in principal and less than $0.1 million in accrued interest.

Cash and cash equivalents available at September 30, 2017, were $4.2 million, combined with $300.0 million credit facility capacity for total liquidity of $304.2 million.

At September 30, 2017, and December 31, 2016, Cleco Power had a working capital surplus of $131.6 million and $149.1 million, respectively. The $17.5 milliondecrease in working capital is primarily due to:

• a $32.0 million increase in taxes payable primarily due to timing of property tax payments, partially offset by lower income taxes,

• a $17.3 million decrease in cash and cash equivalents,

• a $14.2 million decrease in restricted cash and cash equivalents,

• a $13.2 increase in interest accrued primarily due to timing of interest payments,

• a $6.5 million increase in short-term debt primarily due to outstanding borrowings on an uncommitted line of credit, and

• a $5.7 million increase in other current liabilities primarily due to accruals for SSR payments received for capital expenditures, and timing of benefits and incentives.

These decreases in working capital were partially offset by:

• a $26.2 million increase in customer accounts receivable and unbilled revenue primarily due to the normal seasonal fluctuations in retail revenue, timing of receipts from a wholesale customer and additional deferred arrangements due to the LPSC executive orders,

• a $17.4 million decrease in accounts payable primarily due to the timing of property tax and vendor payments,

• a $14.2 million increase in other accounts receivable primarily due to higher receivables for a lignite fuel credit, an insurance reimbursement, SSR payments, and timing of pole attachment receivables,

• a $9.4 million decrease in provision for merger commitments primarily due to the issuance of Merger rate credits, and

• a $5.4 million increase in fuel inventory primarily due to higher petroleum coke and limestone due to lower plant operations and higher coal purchases, partially offset by lower lignite purchases.

Credit Facilities

At September 30, 2017, Cleco Holdings had a $100.0 million credit facility. The credit facility includes restricted financial covenants and expires in 2021. At September 30, 2017, Cleco Holdings was in compliance with the covenants of its 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%. If Cleco Holdings’ credit ratings were to be downgraded one level by either agency, Cleco

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Holdings would 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 September 30, 2017, Cleco Power had a $300.0 million credit facility The credit facility includes restricted financial covenants and expires in 2021. At September 30, 2017, 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 by either agency, Cleco Power would 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 September 30, 2017, and December 31, 2016, 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 Quarterly Report on Form 10-K for the year ended December 31, 2016.

Cleco Consolidated Cash Flows

Net Operating Cash Flow

Cleco’s net cash provided by operating activities for the successor period January 1, 2017, through September 30, 2017, was $246.9 million. There were no significant changes in the underlying trends impacting cash provided by operating activities.

Cleco’s net cash provided by operating activities for the successor period April 13, 2016, through September 30, 2016, was $66.7 million. There were no significant changes in the underlying trends impacting cash provided by operating activities with the exception of $23.9 million related to payments for merger transaction costs during the successor period.

Cleco’s net cash provided by operating activities for the predecessor period January 1, 2016, through April 12, 2016, was $129.8 million. There were no significant changes in the underlying trends impacting cash provided by operating activities.

Net Investing Cash Flow

Cleco’s net cash used in investing activities for the successor period January 1, 2017, through September 30, 2017, was $166.3 million. There were no significant changes in the underlying trends impacting cash used in investing activities.

Cleco’s net cash used in investing activities for the successor period April 13, 2016, through September 30, 2016, was $133.3 million. There were no significant changes in the underlying trends impacting cash used in investing activities with the exception of $147.8 million transferred into restricted cash and cash equivalents due to the funding of customer rate credits and charitable contributions as a result of the Merger Commitments. In addition, $113.9 million was transferred out of restricted cash and cash equivalents to pay for a portion of the Merger Commitments.

Cleco’s net cash used in investing activities for the predecessor period January 1, 2016, through April 12, 2016, was $36.8 million. There were no significant changes in the underlying trends impacting cash used in investing activities.

Net Financing Cash Flow

Cleco’s net cash used in financing activities for the successor period January 1, 2017, through September 30, 2017, was $97.6 million. There were no significant changes in the underlying trends impacting cash used in financing activities with the exception of Cleco Holdings no longer having dividends to stockholders after the Merger.

Cleco’s net cash provided by financing activities for the successor period April 13, 2016, through September 30, 2016, was $27.8 million. There were no significant changes in the underlying trends impacting cash provided by financing activities with the exception of $100.7 million in contributions from Cleco Group.

Cleco’s net cash used in financing activities for the predecessor period January 1, 2016, through April 12, 2016, was $40.9 million. There were no significant changes in the underlying trends impacting cash used in financing activities.

Cleco Power Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $236.0 million and $214.5 million during the nine months ended September 30, 2017, and 2016, respectively. Net cash provided by operating activities increased$21.5 million primarily due to:

• higher collections from customers of $101.9 million due to the absence of the Merger credits issued in 2016 and

• higher net fuel and power purchase collections of $14.7 million primarily due to timing of recovery.

These increases were partially offset by:

• higher payments for fuel inventory of $40.9 million primarily due to petroleum coke and coal purchases,

• higher payments to vendors of $10.2 million primarily related to the timing of property taxes,

• lower receipts of $7.9 million from joint owners’ portions of generating station expenditures,

• lower collections of $7.3 million due to LPSC executive orders relating to 2016 flooding,

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• lower receipts of advanced deposits for operations and maintenance costs on jointly owned generating units of $5.8 million, and

• higher payments of $1.3 million related to storm restoration efforts.

Net Investing Cash Flow

Net cash used in investing activities was $164.9 million and $171.0 million during the nine months ended September 30, 2017, and 2016, respectively. Net cash used in investing activities decreased $6.1 million primarily due to lower transfers of cash to restricted accounts of $42.2 million due to funding the Merger Commitments in 2016. This decrease was partially offset by higher additions to property, plant, and equipment of $39.0 million.

Net Financing Cash Flow

Net cash used in financing activities was $88.4 million and $53.9 million during the nine months ended September 30, 2017, and 2016, respectively. Net cash used in financing activities increased $34.5 million. Included in this net increase was the absence of contributions from Cleco Holdings of $50.0 million to help fund the Merger Commitments, partially offset by lower distributions to Cleco Holdings of $10.0 million and $6.5 million for net borrowings on Cleco Power’s uncommitted line of credit.

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, 2016.

Off-Balance Sheet Commitments and Guarantees

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

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 its FRP. If Cleco fails to comply with these revisions, reinterpretations, and requirements, it could be subject to civil or criminal liabilities and fines.

On March 28, 2017, the President signed a broad executive order. Among other measures, the order directed the EPA to review the Clean Power Plan (CPP), the proposed Federal Implementation Plan for the CPP, and the greenhouse gas new source performance standards (GHG NSPS). It also gave the U.S. Department of Justice discretion to request that the U.S. Court of Appeals of the D.C. Circuit stay or otherwise delay the litigation challenging the CPP and the GHG NSPS while the administrative review is underway. Until the directions of the executive order are carried out, management cannot predict what the final standards will entail or what controls the EPA and the state of Louisiana may require of Cleco in a final state implementation plan.

In the second quarter of 2015, Cleco Power began incurring additional environmental compliance expenses for reagents associated with compliance with MATS. For a discussion about MATS, 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.”

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, 2016.

Retail Rates of Cleco Power

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. In February 2016, the LPSC initiated an audit of Cleco Power’s fuel and purchased power expenses for the period January 2014 through December 2015. The total amount of fuel expense included in the audit was $582.6 million. On January 19, 2017, the LPSC Staff issued its audit report which recommended no disallowance of fuel costs. The report was approved by the LPSC on April 19, 2017. Cleco Power has FAC filings for January 2016 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings.

For information concerning Cleco Power’s current FRP and amounts accrued and refunded by Cleco Power as a result of the FRP, and information on the LPSC Staff’s FRP reviews, see

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Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 10 — Regulation and 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. 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. In February 2016, the LPSC initiated an audit of Cleco Power’s environmental costs for the period November 2010 through December 2015. The total amount of environmental costs included in the audit was $81.2 million. In December 2016, the LPSC Staff issued its audit report which recommended a disallowance of environmental costs of less than $0.1 million. The report was approved by the LPSC on February 17, 2017. Cleco Power has EAC filings for January 2016 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. In the second quarter of 2015, Cleco Power began incurring additional environmental compliance expenses for reagents associated with compliance with MATS. These expenses are eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC. For more information on MATS, 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.”

In April 2016, the LPSC issued Docket No. R-34026 to investigate double leveraging issues for all LPSC-jurisdictional utilities whereby double leveraging is utilized to fund a utility’s capital structure, and to consider whether any costs associated with such double leveraging should be included in the rates paid by the utility’s retail customers. Cleco Power filed a motion to intervene in this proceeding along with other Louisiana utilities. In April 2016, the LPSC also issued Docket No. R-34029 to investigate tax structure issues for all LPSC-jurisdictional utilities to consider whether only the state and federal taxes included in a utility’s retail rate will be those that do not exceed the utility’s share of the actual taxes paid to those federal and state taxing authorities. Cleco Power filed a motion to intervene in this proceeding along with other Louisiana utilities. In October 2016, Cleco received the first set of data requests from the LPSC Staff for each of the above mentioned dockets. Cleco has filed responses to the non-confidential requests and is waiting on the completion of a confidentiality agreement to respond to the confidential requests. Cleco is unable to determine if or when the completion of this confidentiality agreement will occur. If the LPSC were to disallow such costs incurred by the utility to be included in retail rates, such disallowance could have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.

For information on certain other regulatory aspects of retail rates concerning 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 — Retail Rates of Cleco Power” in the

Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2016.

SSR

In September 2016, Cleco Power filed an Attachment Y with MISO requesting retirement of Teche Unit 3 effective April 1, 2017. MISO conducted a study which determined the proposed retirement of Teche Unit 3 would result in violations of specific applicable reliability standards for which no mitigation is available. As a result, MISO designated Teche Unit 3 as an SSR unit until such time that an appropriate alternative solution can be implemented to mitigate reliability issues. One mitigating factor that has been identified is Cleco Power’s Terrebonne to Bayou Vista Transmission project, which is expected to be complete by the third quarter of 2018. Cleco Power has a 12-month SSR Agreement for the period April 1, 2017 to March 31, 2018. During this time, Cleco Power will continue to operate Teche Unit 3. Cleco Power has filed with FERC for its approval to collect $20.3 million annually in SSR payments from MISO which includes 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 Agreement. At the end of the agreement, 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 September 30, 2017, Cleco Power had $2.2 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 request from FERC staff and intervenors. The next settlement conference is scheduled for November 16, 2017. Cleco Power is unable to determine when a binding FERC order will be issued. Also 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. In the first quarter of 2018, another study is expected to be performed by MISO to determine if an SSR Agreement will be needed after March 31, 2018. 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.

Energy Efficiency

In August 2009, the LPSC opened a docket to study the promotion of energy efficiency by jurisdictional electric and natural gas utilities. In September 2013, the LPSC issued a General Order adopting rules promoting energy efficiency programs. Cleco Power subsequently filed its formal intent with the LPSC to participate in the Phase I - Quick Start portion of the LPSC’s energy efficiency initiative, which began in November 2014, and has been extended through the start of Phase II, which is anticipated to be in 2019 or later. During Phase I, Cleco Power designed several energy efficiency programs and began offering these programs to customers in November 2014. In November 2014, Cleco Power began

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recovering approximately $3.3 million annually of estimated costs for the program though an approved rate tariff. In January 2017, the LPSC amended its Phase I — Quick Start program to allocate no less than 50% of its annual program budgets to applicable government and state agencies. Cleco Power’s participation in the amended program is also projected to be $3.3 million annually as approved by the LPSC in September 2017.

In September 2017, the LPSC approved a motion for additional energy efficiency programs for the exclusive benefit of school districts, local governments, state agencies, and higher education institutions or any other public entities. The recovery of approximately $3.3 million annually for estimated costs for the program is expected to begin in January 2018.

MISO Cost Benefit Analysis

Cleco Power entered into MISO in December 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 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 is to be filed with FERC every three years or upon the occurrence of a change in status as defined by FERC regulation. In February 2014, FERC issued an order to accept Cleco’s substitute market power analysis and grant the power marketing entities the authority to continue to charge market-based rates for wholesale power. Cleco filed its triennial market power analysis with FERC in January 2015. In March 2016, FERC issued an order finding Cleco’s submittal satisfies its requirements for market-based rate authority regarding both horizontal and vertical market power. Cleco’s next triennial market power analysis will be filed by December 31, 2017.

Transmission Rates of Cleco Power

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”.

On May 1, 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.

Cleco Power is unable to determine when FERC will approve the rate increase and if any refund will be required.

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, 2016.

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, 2016.

Transmission and Generation Projects

Cleco Power is involved in several transmission projects, including the Cenla Transmission Expansion project and the Terrebonne to Bayou Vista Transmission project. Cleco Power is also currently 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, 2016.

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.

The SPP Regional Entity (RE) conducts a NERC Reliability Standard audit every three years. Cleco Power’s next audit is scheduled to begin in April 2019. Management is unable to predict the outcome of this audit, 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.

The SPP RE also conducts a NERC Critical Infrastructure Protection audit every three years. A NERC Critical Infrastructure Protection audit was conducted in February 2017. Based on the evidence provided, the SPP RE determined there were three instances of potential noncompliance. These findings are not expected to have a material adverse effect on the results of operations, financial condition, or cash flows of the Registrants.

On July 23, 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, which will effectively dissolve the SPP RE by the end of 2018. On October 12, 2017, Cleco Power proposed a new RE to NERC. Once NERC approves a new RE, it will

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then need to be approved by FERC. Management does not expect this termination to have a significant impact 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, 2016.

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, 2016.

Lignite Deferral

At September 30, 2017, and December 31, 2016, Cleco Power had $4.5 million and $6.4 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, 2016.

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. The IRP process includes conducting stakeholder meetings and receiving feedback from stakeholders. The schedule outlined in the General Order calls for Cleco Power to file a draft IRP in October 2018, and a final report in May 2019.

Service Quality Program (SQP)

In October 2015, the LPSC proposed an SQP containing 21 requirements for Cleco Power. The SQP has provisions relating to employee headcount, customer service, reliability, vegetation management, and reporting. In April 2016, the SQP was approved by the LPSC. The SQP will remain in effect until 2021. Prior to the expiration of the SQP, a new five-year program must be negotiated and submitted to the LPSC for approval. Cleco Power filed its annual monitoring report on April 1, 2017.

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.

On April 11, 2017, the City of Slidell voted to approve a new franchise agreement with Cleco Power with an effective date of April 11, 2017. The franchise agreement is for 35 years until April 2052. Approximately 13,823 Cleco Power customers are located in the City of Slidell.

On July 13, 2017, the Town of Rosepine and the Town of Cheneyville voted to approve new franchise agreements with

Cleco Power with an effective date of July 13, 2017. Both franchise agreements are for 33 years until July 2050. Approximately 916 Cleco Power customers are located in the Town of Rosepine, and approximately 356 Cleco Power customers are located in the Town of Cheneyville.

On October 24, 2017, the Town of New Llano voted to approve a new franchise agreement with Cleco Power with an effective date of October 24, 2017. The franchise agreement is for 15 years until October 2032. Cleco Power currently serves seven customers located in the town of New Llano. This new franchise agreement provides Cleco Power the opportunity to compete for future growth opportunities in the town.

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, 2016.

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, 2016.

Business Combinations

On April 13, 2016, Cleco Holdings completed its merger with Merger Sub whereby Merger Sub 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, as a direct, wholly owned subsidiary of Cleco Group and an indirect, wholly owned subsidiary of Cleco Partners. The merger transaction required the use of the acquisition method to account for business combinations. The objective of this method is to establish a new accounting basis for the acquiree. Cleco Holdings’ assets and liabilities were measured and recorded at fair value as of the acquisition date. Cleco Power’s assets and liabilities were recorded at historical cost since Cleco did not elect pushdown accounting at the Cleco Power level. The financial statements and accompanying footnotes for Cleco

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have been segregated to present pre-merger activity as the “Predecessor” and post-merger activity as the “Successor.” The predecessor period is not comparable to the successor period. For more information, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 2 — Business Combinations.”

Goodwill

On April 13, 2016, in connection with the completion of the Merger, Cleco recognized goodwill of $1.49 billion. Goodwill is required to be tested for impairment at the reporting segment level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting segment below its carrying value. For more information on goodwill and its impairment testing, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — Goodwill.”

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 April 7, 2017, Moody’s updated its credit ratings by maintaining Cleco Holdings at Baa3 (stable) and Cleco Power at A3 (stable). On May 30, 2017, S&P affirmed Cleco Holdings’ and Cleco Power’s credit ratings at BBB- (stable) and BBB+ (stable), respectively. If Cleco Holdings or Cleco Power’s credit ratings were to be downgraded by S&P or Moody’s, Cleco Holdings and/or Cleco Power would be required to pay additional fees and incur higher interest rates for borrowings under their respective credit facilities.

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 September 30, 2017, 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 September 30, 2017, 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 September 30, 2017, the all-in rate was 2.87%. 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 a discussion on the short- and long-term variable-rate debt related to Cleco Power, please refer to “— Cleco Power.”

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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 September 30, 2017. In June 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. This proposal was submitted to the LPSC on July 28, 2017. An ALJ was assigned to the docket and a status conference was held on October 3, 2017. A procedural schedule was determined and management expects a final determination in the second quarter of 2018.

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 September 30, 2017, Cleco Power’s Condensed Consolidated Balance Sheets reflected open FTR positions of $13.4 million in Energy risk management assets and $0.5 million in Energy risk management 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 September 30, 2017, Cleco Power had $6.5 million of short-term variable-rate debt outstanding on an uncommitted line of credit at an all-in interest rate of 2.98%. Each 1% increase in the interest rate applicable to such debt would result in a decrease in Cleco Power’s pretax earnings of $0.1 million.

At September 30, 2017, Cleco Power had 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.

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

As of September 30, 2017, evaluations were performed under the supervision and with the participation of Cleco Holdings and Cleco Power (individually, “Registrant” and collectively, the “Registrants”) management, including the Interim CEOs and CFO. The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures. Based on the evaluations, the Interim CEOs 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 Interim CEOs 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 September 30, 2017, 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

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, 2016 (the “2016 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 2016 Annual Report on Form 10-K.

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.

ITEM 6.   EXHIBITS
CLECO
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

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CLECO POWER	2017 3RD 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: November 9, 2017

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: November 9, 2017

65

EX-12.A

CLECO CORPORATE HOLDINGS LLC EXHIBIT 12(a)

Computation of Ratios of Earnings to Fixed Charges (Unaudited)
	SUCCESSOR						PREDECESSOR
(THOUSANDS, EXCEPT RATIOS)	FOR THE NINE MONTHS ENDED SEPT. 30, 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			FOR THE TWELVE MONTHS ENDED DEC. 31, 2013
Net income (loss)	$	77,041		$	(24,113	)	$	(3,960	)	$	133,669		$	154,739		$	160,685
Income tax expense (benefit)	42,381			(22,822		)	3,468			77,704			67,116			79,575
Undistributed equity loss from investees	—			—			—			7			—			—
Amortization of capitalized interest	—			—			—			—			77			308
Total fixed charges (from below)	94,507			91,338			22,547			79,795			76,163			86,680
Total earnings	$	213,929		$	44,403		$	22,055		$	291,175		$	298,095		$	327,248
Fixed charges
Interest	$	89,119		$	87,315		$	21,491		$	75,535		$	71,959		$	81,173
Amortization of debt expense, premium, net	4,958			3,537			839			3,342			3,227			4,397
Portion of rentals representative of an interest factor**	389			362			146			572			489			488
Interest of capitalized lease	41			124			71			346			488			622
Total fixed charges	$	94,507		$	91,338		$	22,547		$	79,795		$	76,163		$	86,680
Ratio of earnings to fixed charges	2.26		x	*			*			3.65		x	3.91		x	3.78		x
*Earnings were inadequate to cover fixed charges.
**Interest portion of rental expense is estimated to equal 11% of such expense, which is considered a reasonable approximation of the interest factor.

EX-12.B

CLECO POWER LLC EXHIBIT 12(b)

Computation of Ratios of Earnings to Fixed Charges (Unaudited)
(THOUSANDS, EXCEPT RATIOS)	FOR THE NINE MONTHS ENDED SEPT. 30, 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			FOR THE TWELVE MONTHS ENDED DEC. 31, 2013
Net income	$	108,439		$	39,128		$	141,350		$	154,316		$	150,410
Income tax expense	63,010			18,369			79,294			76,974			79,381
Total fixed charges (from below)	54,361			78,442			78,364			77,230			85,103
Total earnings	$	225,810		$	135,939		$	299,008		$	308,520		$	314,894
Fixed charges
Interest	$	49,922		$	74,450		$	74,394		$	73,140		$	80,905
Amortization of debt expense, premium, net	4,009			3,289			3,052			3,113			3,088
Portion of rentals representative of an interest factor**	389			508			572			489			488
Interest of capitalized lease	41			195			346			488			622
Total fixed charges	$	54,361		$	78,442		$	78,364		$	77,230		$	85,103
Ratio of earnings to fixed charges	4.15		x	1.73		x	3.82		x	3.99		x	3.70		x
**Interest portion of rental expense is estimated to equal 11% of such expense, which is considered a reasonable approximation of the interest factor.

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, Peggy B. Scott, certify that:

1. I have reviewed this quarterly report on Form 10-Q for the quarter ended September 30, 2017, 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:   November 9, 2017

/s/ Peggy B. Scott

Peggy B. Scott

Interim 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 September 30, 2017, 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:   November 9, 2017

/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 September 30, 2017, 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:  November 9, 2017

/s/  William G. Fontenot

William G. Fontenot

Interim 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 September 30, 2017, 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:   November 9, 2017

/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 September 30, 2017, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Peggy B. Scott, Interim 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:   November 9, 2017

/s/  Peggy B. Scott

Peggy B. Scott

Interim 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 September 30, 2017, 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:   November 9, 2017

/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 September 30, 2017, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, William G. Fontenot, Interim 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:   November 9, 2017

/s/  William G. Fontenot

William G. Fontenot

Interim 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 September 30, 2017, 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:  November 9, 2017

/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 third quarter of 2017, DHLC was issued two citations that were considered non significant and substantial. The amounts assessed and paid were immaterial. Also in the third quarter of 2017, four significant and substantial citations that were issued to DHLC in the second quarter of 2017 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	9 Months Ended
	Sep. 30, 2017	Nov. 09, 2017
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	Sep. 30, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		0
Cleco Power [Member]
Entity Information [Line Items]
Entity Registrant Name	CLECO POWER LLC
Entity Central Index Key	0000018672
Entity Filer Category	Non-accelerated Filer

XML

Consolidated Statements of Income - USD ($) $ in Thousands	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Operating revenue [Abstract]
Electric operations	$ 317,589	$ 323,707
Other operations	21,282	18,976
Affiliate revenue	0	0
Gross operating revenue	338,871	342,683
Electric customer credits	(372)	177
Operating revenue, net	338,499	342,860
Operating expenses [Abstract]
Fuel used for electric generation	103,217	101,908
Power purchased for utility customers	39,355	36,058
Other operations	27,957	35,361
Maintenance	18,031	19,412
Depreciation and amortization	42,228	42,535
Taxes other than income taxes	12,414	12,574
Merger transaction and commitment costs	185	1,869
Total operating expenses	243,387	249,717
Operating (loss) income	95,112	93,143
Interest income	354	318
Allowance for equity funds used during construction	2,096	1,308
Other income	2,557	658
Other expense	(1,299)	(248)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	31,110	32,233
Allowance for borrowed funds used during construction	(648)	(375)
Total interest charges	30,462	31,858
(Loss) income before income taxes	68,358	63,321
Federal and state income tax (benefit) expense	23,054	23,700
Net (loss) income	45,304	39,621			$ 77,041
Predecessor
Operating revenue [Abstract]
Electric operations			$ 281,154
Other operations			19,080
Affiliate revenue			0
Gross operating revenue			300,234
Electric customer credits			(364)
Operating revenue, net			299,870
Operating expenses [Abstract]
Fuel used for electric generation			96,378
Power purchased for utility customers			27,249
Other operations			33,563
Maintenance			29,813
Depreciation and amortization			44,076
Taxes other than income taxes			14,611
Merger transaction and commitment costs			34,912
Gain on sale of asset			(1,095)
Total operating expenses			279,507
Operating (loss) income			20,363
Interest income			265
Allowance for equity funds used during construction			723
Other income			870
Other expense			(590)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net			22,330
Allowance for borrowed funds used during construction			(207)
Total interest charges			22,123
(Loss) income before income taxes			(492)
Federal and state income tax (benefit) expense			3,468
Net (loss) income			$ (3,960)
Successor
Operating revenue [Abstract]
Electric operations				$ 553,634	839,080
Other operations				33,110	59,627
Affiliate revenue				0	0
Gross operating revenue				586,744	898,707
Electric customer credits				(381)	(1,045)
Operating revenue, net				586,363	897,662
Operating expenses [Abstract]
Fuel used for electric generation				168,159	261,063
Power purchased for utility customers				60,439	114,675
Other operations				59,633	89,201
Maintenance				42,317	66,955
Depreciation and amortization				76,695	124,630
Taxes other than income taxes				22,953	36,790
Merger transaction and commitment costs				173,172	187
Gain on sale of asset				0	0
Total operating expenses				603,368	693,501
Operating (loss) income				(17,005)	204,161
Interest income				515	1,046
Allowance for equity funds used during construction				2,057	4,446
Other income				2,395	4,402
Other expense				(435)	(1,833)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net				58,926	94,077
Allowance for borrowed funds used during construction				(603)	(1,277)
Total interest charges				58,323	92,800
(Loss) income before income taxes				(70,796)	119,422
Federal and state income tax (benefit) expense				(28,502)	42,381
Net (loss) income				$ (42,294)	77,041
Cleco Power [Member]
Operating revenue [Abstract]
Electric operations	320,009	326,281			847,417	$ 839,593
Other operations	20,768	18,460			58,083	50,638
Affiliate revenue	209	213			649	669
Gross operating revenue	340,986	344,954			906,149	890,900
Electric customer credits	(372)	177			(1,045)	(745)
Operating revenue, net	340,614	345,131			905,104	890,155
Operating expenses [Abstract]
Fuel used for electric generation	103,217	101,908			261,063	264,537
Power purchased for utility customers	39,355	36,058			114,675	87,688
Other operations	28,680	35,886			90,453	94,566
Maintenance	17,812	19,326			66,496	71,818
Depreciation and amortization	40,049	40,353			118,280	115,196
Taxes other than income taxes	12,008	12,180			35,412	36,096
Merger transaction and commitment costs					0	151,501
Gain on sale of asset					0	(1,095)
Total operating expenses	241,121	245,711			686,379	820,307
Operating (loss) income	99,493	99,420			218,725	69,848
Interest income	332	264			926	590
Allowance for equity funds used during construction	2,096	1,308			4,446	2,780
Other income	1,463	629			1,839	828
Other expense	(1,299)	(445)			(1,833)	(1,082)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	17,789	19,552			53,931	58,587
Allowance for borrowed funds used during construction	(648)	(375)			(1,277)	(810)
Total interest charges	17,141	19,177			52,654	57,777
(Loss) income before income taxes	84,944	81,999			171,449	15,187
Federal and state income tax (benefit) expense	30,092	29,427			63,010	2,965
Net (loss) income	$ 54,852	$ 52,572			$ 108,439	$ 12,222

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Net (loss) income	$ 45,304	$ 39,621			$ 77,041
Other comprehensive (loss) income, net of tax [Abstract]
Postretirement benefits (loss) gain, net of tax	(44)	(2,305)
Total other comprehensive (loss) income, net of tax	(44)	(2,305)			(2,175)
Comprehensive (loss) income, net of tax	45,260	37,316
Successor
Net (loss) income				$ (42,294)	77,041
Other comprehensive (loss) income, net of tax [Abstract]
Postretirement benefits (loss) gain, net of tax				(2,305)	(2,175)
Amortization of interest rate derivatives to earnings, net of tax				0	0
Total other comprehensive (loss) income, net of tax				(2,305)	(2,175)
Comprehensive (loss) income, net of tax				$ (44,599)	74,866
Predecessor
Net (loss) income			$ (3,960)
Other comprehensive (loss) income, net of tax [Abstract]
Postretirement benefits (loss) gain, net of tax			587
Amortization of interest rate derivatives to earnings, net of tax			60
Total other comprehensive (loss) income, net of tax			647
Comprehensive (loss) income, net of tax			$ (3,313)
Cleco Power [Member]
Net (loss) income	54,852	52,572			108,439	$ 12,222
Other comprehensive (loss) income, net of tax [Abstract]
Postretirement benefits (loss) gain, net of tax	167	2,180			(60)	2,561
Amortization of interest rate derivatives to earnings, net of tax	53	53			159	159
Total other comprehensive (loss) income, net of tax	220	2,233			99	2,720
Comprehensive (loss) income, net of tax	$ 55,072	$ 54,805			$ 108,538	$ 14,942

XML

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Net tax expense (benefit) of gain (loss) on postretirement benefits	$ (26)	$ (1,442)
Net tax expense on cash flow hedges	0	0
Successor
Net tax expense (benefit) of gain (loss) on postretirement benefits				$ (1,442)	$ (1,359)
Net tax expense on cash flow hedges				$ 0	0
Predecessor
Net tax expense (benefit) of gain (loss) on postretirement benefits			$ 367
Net tax expense on cash flow hedges			$ 37
Cleco Power [Member]
Net tax expense (benefit) of gain (loss) on postretirement benefits	104	1,364			(38)	$ 1,602
Net tax expense on cash flow hedges	$ 33	$ 33			$ 99	$ 99

XML

Consolidated Balance Sheets - USD ($)	Sep. 30, 2017	Dec. 31, 2016
Current assets [Abstract]
Cash and cash equivalents	$ 6,127,000	$ 23,077,000
Restricted cash and cash equivalents	8,874,000	23,084,000
Customer accounts receivable (less allowance for doubtful accounts)	78,313,000	56,780,000
Other accounts receivable	33,934,000	19,778,000
Unbilled revenue	38,912,000	34,268,000
Fuel inventory, at average cost	51,847,000	46,410,000
Materials and supplies, at average cost	84,522,000	81,818,000
Energy risk management assets	13,425,000	7,884,000
Accumulated deferred fuel	21,057,000	20,787,000
Cash surrender value of company-/trust-owned life insurance policies	81,165,000	77,225,000
Prepayments	6,553,000	7,813,000
Regulatory assets	27,636,000	26,803,000
Other current assets	410,000	1,315,000
Total current assets	452,775,000	427,042,000
Property, plant, and equipment [Abstract]
Property, plant, and equipment	3,556,775,000	3,476,581,000
Accumulated depreciation	(162,040,000)	(75,816,000)
Net property, plant, and equipment	3,394,735,000	3,400,765,000
Construction work in progress	163,423,000	78,577,000
Total property, plant, and equipment, net	3,558,158,000	3,479,342,000
Equity investment in investees	18,172,000	18,672,000
Goodwill	1,490,797,000	1,490,797,000
Prepayments	1,887,000	4,731,000
Restricted cash and cash equivalents	24,547,000	23,410,000
Regulatory assets - deferred taxes, net	240,431,000	237,449,000
Regulatory assets	430,893,000	454,644,000
Net investment in direct financing lease	13,381,000	13,420,000
Intangible assets	121,269,000	142,634,000
Tax credit fund investment, net	10,409,000	11,888,000
Other deferred charges	34,982,000	39,115,000
Total assets	6,397,701,000	6,343,144,000
Current liabilities [Abstract]
Short-term debt	6,470,000	0
Long-term debt due within one year	19,193,000	19,715,000
Accounts payable	99,138,000	112,087,000
Customer deposits	58,018,000	56,599,000
Provision for rate refund	3,734,000	3,974,000
Provision for merger commitments	4,945,000	14,371,000
Taxes payable, net	26,894,000	3,942,000
Interest accrued	38,656,000	14,783,000
Energy risk management liabilities	538,000	201,000
Deferred compensation	11,604,000	11,654,000
Other current liabilities	21,309,000	14,850,000
Total current liabilities	290,499,000	252,176,000
Long-term liabilities and deferred credits [Abstract]
Accumulated deferred federal and state income taxes, net	1,075,869,000	1,033,055,000
Accumulated deferred investment tax credits	2,254,000	2,751,000
Postretirement benefit obligations	230,203,000	223,003,000
Restricted storm reserve	18,189,000	17,385,000
Other deferred credits	29,430,000	29,440,000
Total long-term liabilities and deferred credits	1,355,945,000	1,305,634,000
Long-term debt, net	2,713,583,000	2,738,571,000
Total liabilities	4,360,027,000	4,296,381,000
Commitments and Contingencies (Note 12)
Member's equity [Abstract]
Membership interest	1,985,421,000	2,069,376,000
Retained earnings/Accumulated deficit	52,928,000	(24,113,000)
Accumulated other comprehensive (loss) income	(675,000)	1,500,000
Total member’s equity	2,037,674,000	2,046,763,000
Total liabilities and member’s equity	6,397,701,000	6,343,144,000
Cleco Power [Member]
Current assets [Abstract]
Cash and cash equivalents	4,227,000	21,482,000
Restricted cash and cash equivalents	8,874,000	23,084,000
Customer accounts receivable (less allowance for doubtful accounts)	78,313,000	56,780,000
Accounts receivable - affiliate	1,545,000	1,406,000
Other accounts receivable	33,676,000	19,457,000
Taxes receivable, net	0	12,490,000
Unbilled revenue	38,912,000	34,268,000
Fuel inventory, at average cost	51,847,000	46,410,000
Materials and supplies, at average cost	84,522,000	81,818,000
Energy risk management assets	13,425,000	7,884,000
Accumulated deferred fuel	21,057,000	20,787,000
Cash surrender value of company-/trust-owned life insurance policies	20,216,000	20,018,000
Prepayments	5,367,000	5,892,000
Regulatory assets	18,779,000	17,721,000
Other current assets	0	577,000
Total current assets	380,760,000	370,074,000
Property, plant, and equipment [Abstract]
Property, plant, and equipment	4,858,764,000	4,790,565,000
Accumulated depreciation	(1,687,337,000)	(1,618,241,000)
Net property, plant, and equipment	3,171,427,000	3,172,324,000
Construction work in progress	162,500,000	77,306,000
Total property, plant, and equipment, net	3,333,927,000	3,249,630,000
Equity investment in investees	18,172,000	18,672,000
Prepayments	1,887,000	4,731,000
Restricted cash and cash equivalents	24,526,000	23,389,000
Regulatory assets - deferred taxes, net	240,431,000	237,449,000
Regulatory assets	253,146,000	268,016,000
Intangible assets	45,636,000	58,473,000
Other deferred charges	33,020,000	37,014,000
Total assets	4,331,505,000	4,267,448,000
Current liabilities [Abstract]
Short-term debt	6,470,000	0
Long-term debt due within one year	19,193,000	19,715,000
Accounts payable	92,522,000	101,874,000
Accounts payable - affiliate	8,293,000	7,190,000
Customer deposits	58,018,000	56,599,000
Provision for rate refund	3,734,000	3,974,000
Provision for merger commitments	4,945,000	14,371,000
Taxes payable, net	19,487,000	0
Interest accrued	20,348,000	7,141,000
Energy risk management liabilities	538,000	201,000
Other current liabilities	15,659,000	9,951,000
Total current liabilities	249,207,000	221,016,000
Long-term liabilities and deferred credits [Abstract]
Accumulated deferred federal and state income taxes, net	1,084,482,000	1,068,592,000
Accumulated deferred investment tax credits	2,254,000	2,751,000
Postretirement benefit obligations	164,183,000	159,107,000
Restricted storm reserve	18,189,000	17,385,000
Other deferred credits	27,483,000	28,339,000
Total long-term liabilities and deferred credits	1,296,591,000	1,276,174,000
Long-term debt, net	1,216,967,000	1,235,056,000
Total capitalization	2,785,707,000	2,770,258,000
Commitments and Contingencies (Note 12)
Member's equity [Abstract]
Total member’s equity	1,568,740,000	1,535,202,000
Total liabilities and member’s equity	$ 4,331,505,000	$ 4,267,448,000

XML

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Current assets [Abstract]
Customer accounts receivable, allowance for doubtful accounts	$ 2,102	$ 7,199
Cleco Power [Member]
Current assets [Abstract]
Customer accounts receivable, allowance for doubtful accounts	$ 2,102	$ 7,199

XML

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended	6 Months Ended	9 Months Ended
	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Operating activities [Abstract]
Net (loss) income			$ 77,041
Financing activities [Abstract]
Cash and cash equivalents at beginning of period			23,077
Cash and cash equivalents at end of period			6,127
Predecessor
Operating activities [Abstract]
Net (loss) income	$ (3,960)
Adjustments to reconcile net income (loss) to net cash provided by operating activities [Abstract]
Depreciation and amortization	45,869
Gain on sale of asset	(1,095)
Provision for doubtful accounts	1,212
Unearned compensation expense	3,276
Allowance for equity funds used during construction	(724)
Deferred income taxes	2,219
Deferred fuel costs	977
Cash surrender value of company-/trust-owned life insurance	(840)
Changes in assets and liabilities [Abstract]
Accounts receivable	(1,865)
Accounts receivable, affiliate	0
Unbilled revenue	563
Fuel inventory and materials and supplies	19,312
Prepayments	2,395
Accounts payable	8,348
Customer deposits	3,342
Provision for merger commitments	0
Postretirement benefit obligations	9,746
Regulatory assets and liabilities, net	5,178
Other deferred accounts	6,878
Taxes accrued	10,820
Interest accrued	17,909
Other operating	219
Net cash provided by operating activities	129,779
Investing activities [Abstract]
Additions to property, plant, and equipment	(42,392)
Allowance for equity funds used during construction	724
Proceeds from sale of property	1,932
Contributions to equity investment in investee	(2,450)
Return of equity investment in tax credit fund	476
Transfer of cash (to) from restricted accounts, net	4,847
Other investing	53
Net cash used in investing activities	(36,810)
Financing activities [Abstract]
Proceeds from short-term debt, net	0
Draws on credit facilities	3,000
Payments on credit facilities	(10,000)
Issuance of Long-term Debt	0
Repayment of long-term debt	(8,546)
Payment of Financing Costs	(43)
Dividends paid on common stock	(24,579)
Contributions from member/parent	0
Distributions to member/parent	0
Other financing	(717)
Net cash provided by (used in) financing activities	(40,885)
Net (decrease) increase in cash and cash equivalents	52,084
Cash and cash equivalents at beginning of period	68,246	$ 120,330		$ 68,246
Cash and cash equivalents at end of period	120,330
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized	2,478
Income taxes paid (refunded), net	(481)
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment	10,619
Non-cash additions to property, plant, and equipment	0
Successor
Operating activities [Abstract]
Net (loss) income		(42,294)	77,041
Adjustments to reconcile net income (loss) to net cash provided by operating activities [Abstract]
Depreciation and amortization		104,561	140,433
Gain on sale of asset		0	0
Provision for doubtful accounts		1,932	2,694
Unearned compensation expense		769	2,809
Allowance for equity funds used during construction		(2,056)	(4,446)
Deferred income taxes		(25,681)	41,192
Deferred fuel costs		(11,489)	4,231
Cash surrender value of company-/trust-owned life insurance		(2,198)	(3,940)
Changes in assets and liabilities [Abstract]
Accounts receivable		(23,157)	(44,139)
Accounts receivable, affiliate		(3,794)	12
Unbilled revenue		(13,643)	(4,643)
Fuel inventory and materials and supplies		19,464	(6,885)
Prepayments		(236)	5,509
Accounts payable		(15,294)	(22,325)
Customer deposits		5,421	9,317
Provision for merger commitments		40,357	(9,244)
Postretirement benefit obligations		2,267	3,789
Regulatory assets and liabilities, net		9,640	9,430
Other deferred accounts		(2,065)	(6,546)
Taxes accrued		5,006	22,233
Interest accrued		13,479	23,772
Other operating		5,714	6,595
Net cash provided by operating activities		66,703	246,889
Investing activities [Abstract]
Additions to property, plant, and equipment		(102,677)	(185,609)
Allowance for equity funds used during construction		2,056	4,446
Proceeds from sale of property		263	590
Contributions to equity investment in investee		0	0
Return of equity investment in tax credit fund		901	1,223
Transfer of cash (to) from restricted accounts, net		(33,943)	13,073
Other investing		137	7
Net cash used in investing activities		(133,263)	(166,270)
Financing activities [Abstract]
Proceeds from short-term debt, net		0	6,470
Draws on credit facilities		15,000	134,000
Payments on credit facilities		(15,000)	(134,000)
Issuance of Long-term Debt		1,350,000	0
Repayment of long-term debt		(1,358,268)	(17,896)
Payment of Financing Costs		(6,860)	(369)
Dividends paid on common stock		(572)	0
Contributions from member/parent		100,720	0
Distributions to member/parent		(56,000)	(83,955)
Other financing		(1,220)	(1,819)
Net cash provided by (used in) financing activities		27,800	(97,569)
Net (decrease) increase in cash and cash equivalents		(38,760)	(16,950)
Cash and cash equivalents at beginning of period		120,330	23,077
Cash and cash equivalents at end of period	120,330	81,570	6,127	81,570
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized		42,963	64,555
Income taxes paid (refunded), net		256	(6)
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment		15,853	13,083
Non-cash additions to property, plant, and equipment		0	3,015
Cleco Power [Member]
Operating activities [Abstract]
Net (loss) income			108,439	12,222
Adjustments to reconcile net income (loss) to net cash provided by operating activities [Abstract]
Depreciation and amortization			123,911	120,703
Gain on sale of asset			0	(1,095)
Provision for doubtful accounts			2,592	3,014
Unearned compensation expense			1,479	1,394
Allowance for equity funds used during construction			(4,446)	(2,780)
Deferred income taxes			12,847	5,201
Deferred fuel costs			4,231	(10,512)
Changes in assets and liabilities [Abstract]
Accounts receivable			(44,115)	(24,378)
Accounts receivable, affiliate			1,221	1,647
Unbilled revenue			(4,643)	(13,080)
Fuel inventory and materials and supplies			(6,885)	38,776
Prepayments			4,774	1,368
Accounts payable			(19,648)	(9,485)
Accounts payable, affiliate			611	(2,583)
Customer deposits			9,317	8,763
Provision for merger commitments			(9,244)	40,357
Postretirement benefit obligations			3,673	3,656
Regulatory assets and liabilities, net			7,939	13,893
Other deferred accounts			(6,093)	4,813
Taxes accrued			31,258	1,607
Interest accrued			13,207	15,147
Other operating			5,537	5,818
Net cash provided by operating activities			235,962	214,466
Investing activities [Abstract]
Additions to property, plant, and equipment			(183,604)	(144,637)
Allowance for equity funds used during construction			4,446	2,780
Proceeds from sale of property			590	2,195
Contributions to equity investment in investee			0	(2,450)
Transfer of cash (to) from restricted accounts, net			13,073	(29,096)
Other investing			637	190
Net cash used in investing activities			(164,858)	(171,018)
Financing activities [Abstract]
Proceeds from short-term debt, net			6,470	0
Draws on credit facilities			106,000	15,000
Payments on credit facilities			(106,000)	(15,000)
Repayment of long-term debt			(17,896)	(16,814)
Contributions from member/parent			0	50,000
Distributions to member/parent			(75,000)	(85,000)
Other financing			(1,933)	(2,070)
Net cash provided by (used in) financing activities			(88,359)	(53,884)
Net (decrease) increase in cash and cash equivalents			(17,255)	(10,436)
Cash and cash equivalents at beginning of period	$ 65,705		21,482	65,705
Cash and cash equivalents at end of period		$ 55,269	4,227	55,269
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized			36,241	40,153
Income taxes paid (refunded), net			0	(485)
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment			13,072	15,837
Non-cash additions to property, plant, and equipment			$ 3,015	$ 0

XML

Consolidated Statement of Changes in Equity - USD ($) $ in Thousands	Total	Membership Interest [Member]	Retained Earnings / (Accumulated Deficit) [Member]	AOCI [Member]	Cleco Power [Member]	Cleco Power [Member] Members Equity [Member]	Cleco Power [Member] AOCI [Member]
Balances, beginning of period at Dec. 31, 2015							$ (17,092)
Increase (Decrease) in Equity [Roll Forward]
Net (loss) income					$ 12,222
Other comprehensive loss, net of tax					2,720		2,720
Balances, end of period at Sep. 30, 2016				$ (2,305)			(14,372)
Balances, beginning of period at Jun. 30, 2016				0			(16,605)
Increase (Decrease) in Equity [Roll Forward]
Net (loss) income	$ 39,621				52,572
Other comprehensive loss, net of tax	(2,305)			(2,305)	2,233		2,233
Balances, end of period at Sep. 30, 2016				(2,305)			(14,372)
Balances, beginning of period at Dec. 31, 2016	2,046,763	$ 2,069,376	$ (24,113)	1,500	1,535,202	$ 1,548,624	(13,422)
Increase (Decrease) in Equity [Roll Forward]
Distributions to member	(83,955)	(83,955)			(75,000)	(75,000)
Net (loss) income	77,041		77,041		108,439	108,439
Other comprehensive loss, net of tax	(2,175)			(2,175)	99		99
Balances, end of period at Sep. 30, 2017	2,037,674	1,985,421	52,928	(675)	1,568,740	1,582,063	(13,323)
Balances, beginning of period at Jun. 30, 2017				(631)			(13,543)
Increase (Decrease) in Equity [Roll Forward]
Net (loss) income	45,304				54,852
Other comprehensive loss, net of tax	(44)			(44)	220		220
Balances, end of period at Sep. 30, 2017	$ 2,037,674	$ 1,985,421	$ 52,928	$ (675)	$ 1,568,740	$ 1,582,063	$ (13,323)

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Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2017

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, 2016.

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.”

On April 13, 2016, Cleco Holdings completed its merger with Merger Sub whereby Merger Sub 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, as a direct, wholly owned subsidiary of Cleco Group and an indirect, wholly owned subsidiary of Cleco Partners. At the effective time of the Merger, each outstanding share of Cleco Corporation common stock, par value $1.00 per share (other than shares that were owned by Cleco Corporation, Cleco Partners, Merger Sub, or any other direct or indirect wholly owned subsidiary of Cleco Partners or Cleco Corporation), were cancelled and were converted into the right to receive $55.37 per share in cash, without interest, with all dividends payable before the effective time of the Merger.

Cleco Holdings accounted for the merger transaction by applying the acquisition method of accounting. The objective of the acquisition method is to establish a new accounting basis for the acquiree, Cleco Holdings and its subsidiaries, and requires the acquirer, Cleco Group, to recognize and measure the acquiree’s assets and liabilities at fair value as of the acquisition date. Cleco Power’s assets and liabilities were recorded at historical cost since Cleco did not elect pushdown accounting at the Cleco Power level. The financial statements and accompanying footnotes for Cleco have been segregated to present pre-merger activity as the “Predecessor” and post-merger activity as the “Successor.” The predecessor period is not comparable to the successor period.

Goodwill

Goodwill is the excess of the purchase price (consideration transferred and liabilities assumed) over the estimated fair value of net assets of the acquired business and is not subject to amortization. On April 13, 2016, in connection with the completion of the Merger, Cleco recognized goodwill of $1.49 billion. Management assigned goodwill to Cleco’s reportable segment, Cleco Power. Goodwill is required to be tested for impairment at the reporting segment level on an annual basis and between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting segment below its carrying value. Application of the goodwill impairment test requires significant judgments, including the identification of reporting segments, assignments of assets and liabilities to reporting segments, assignment of goodwill to reporting segments, and the determination of the fair value of the reporting segments. Management has determined that Cleco Power is Cleco’s only reporting segment.

Cleco conducted its 2017 annual impairment test using an August 1, 2017, measurement date. The fair value of Cleco’s reporting segment, Cleco Power, was estimated using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market approach, which estimates fair value based on market comparables within the utility and energy industries. Significant assumptions used in these fair value estimates include estimation of future cash flows, long-term rate of growth, the selection of comparable companies, and weighted-average cost of capital (WACC) or discount rate. Changes in these assumptions could materially affect the determination of fair value and goodwill impairment at Cleco Power. Based on the tests performed, management has determined that there was no impairment of Cleco Power’s goodwill as of August 1, 2017.

Management estimated the fair value of Cleco Power’s equity to be $3.34 billion at the August 1, 2017, measurement date. The carrying value of Cleco Power’s equity was approximately $3.25 billion with the excess of the fair value over the carrying value representing 3% or $89.5 million. There were no accumulated impairment charges.

The fair value estimate is particularly sensitive to WACC. WACC takes into account both the after-tax cost of debt and the cost of equity. WACC used for calculating the fair values as of August 1, 2017, was 5.2%. A downgrade in Cleco Power’s debt ratings or a decrease in income tax rates could increase Cleco Power’s after-tax cost of debt. In addition, an increase in interest rates or return required by investors in equity markets could increase Cleco Power’s cost of equity. Any increase in the cost of equity or the cost of debt could materially impact Cleco Power’s fair value estimate. A WACC of 5.1% or 5.3% would have resulted in fair value calculations of $3.43 billion and $3.25 billion, respectively.

The fair value estimate is also sensitive to long-term cash flow growth rates applicable to periods beyond management’s five-year business plan. Management assumed a long-term cash flow growth rate of 2.5% based on historical and projected consumer price inflation, economic indicators, and projected industry growth. Any change in the expected terminal cash flow growth rate could materially impact Cleco Power’s fair value estimate. A terminal cash flow growth rate of 2.4% or 2.6% would have resulted in a fair value calculation of $3.25 billion and $3.43 billion, respectively.

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 SEPT. 30, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,798	$	9,213
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	3,876		12,671
Total current	8,874		23,084
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	17,999		17,379
Cleco Power’s charitable contributions	3,640		4,179
Cleco Power’s rate credit escrow	2,887		1,831
Total non-current	24,547		23,410
Total restricted cash and cash equivalents	$	33,421	$	46,494

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,798	$	9,213
Charitable contributions	1,200		1,200
Rate credit escrow	3,876		12,671
Total current	8,874		23,084
Non-current
Future storm restoration costs	17,999		17,379
Charitable contributions	3,640		4,179
Rate credit escrow	2,887		1,831
Total non-current	24,526		23,389
Total restricted cash and cash equivalents	$	33,400	$	46,473

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, 2016, to September 30, 2017, was due to Cleco Katrina/Rita using $17.9 million for scheduled storm recovery bond principal payments and $3.6 million for related interest payments, partially offset by collections of $16.1 million net of administration fees.

Included in the Merger Commitments were $6.0 million of charitable contributions to be disbursed over five years and $136.0 million of rate credits to eligible customers. In April 2016, in accordance with the Merger Commitments, Cleco Power established the charitable contribution fund and also deposited the rate credit funds into an escrow account. In April 2016, the LPSC voted to issue the rate credits equally to customers with service as of June 30, 2016, beginning in July 2016. As of September 30, 2017, $1.2 million of the charitable contributions and $129.4 million of the rate credits had been released from restricted cash.

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. In June 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. This proposal was submitted to the LPSC on July 28, 2017. An ALJ was assigned to the docket and a status conference was held on October 3, 2017. A procedural schedule was determined and management expects a final determination in the second quarter of 2018. There were no open natural gas positions at September 30, 2017, or December 31, 2016.

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 September 30, 2017, Cleco Power’s Condensed Consolidated Balance Sheets reflected the fair value of open FTR positions of $13.4 million in Energy risk management assets and $0.5 million in Energy risk management liabilities, compared to $7.9 million in Energy risk management assets and $0.2 million in Energy risk management liabilities at December 31, 2016. 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.

Stock-Based Compensation

Prior to the completion of the Merger, Cleco had two stock-based compensation plans: the ESPP and the LTIP. As a result of the completion of the Merger, both stock-based compensation plans were terminated.

Pursuant to the terms of the LTIP, certain officers, key employees, and directors of Cleco were eligible to be granted stock options, restricted stock, also known as non-vested stock, common stock equivalents, and stock appreciation rights. During the predecessor period January 1, 2016, through April 12, 2016, Cleco granted no shares of non-vested stock pursuant to the LTIP. As a result of the Merger on April 13, 2016, all unvested shares outstanding under the LTIP that were granted prior to January 1, 2015, vested at target and were paid out in cash to plan participants. Unvested shares that were granted during 2015 were prorated to the target amount and paid out in cash to plan participants in accordance with the terms of the Merger Agreement.

During the predecessor period January 1, 2016, through April 12, 2016, Cleco reported pretax compensation expense of $3.2 million on non-vested stock with a related tax benefit of $1.2 million. In April 2016, Cleco incurred $2.3 million of merger expense due to the accelerated vesting of the LTIP shares for the predecessor period. For more information about the Merger, see Note 2 — “Business Combinations.”

During the nine months ended September 30, 2016, Cleco Power reported pretax compensation expense of $1.0 million on non-vested stock with a related tax benefit of $0.4 million.

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Business Combination

9 Months Ended

Sep. 30, 2017

Business Combinations [Abstract]

Business Combination

Note 2 — Business Combinations

Regulatory Matters

On March 28, 2016, the LPSC approved the Merger. The LPSC’s written order approving the Merger was issued on April 7, 2016. Approval of the Merger was conditioned upon certain commitments, including $136.0 million of customer rate credits, a $7.0 million one-time contribution for economic development in Cleco Power’s service territory to be administered by the LED, $6.0 million of charitable contributions to be disbursed over five years, and $2.5 million of contributions for economic development for Louisiana state and local organizations to be disbursed over five years. These commitment costs were accrued on April 13, 2016. In addition, the Merger Commitments also included $1.2 million of annual refunds to customers representing cost savings due to the Merger. For more information, see Note 10 — “Regulation and Rates.”

Accounting for the Merger Transaction

The total purchase price consideration was approximately $3.36 billion, which consisted of cash paid to Cleco Corporation shareholders of $3.35 billion and cash paid for Cleco LTIP equity awards of $9.5 million. There were no remaining LTIP equity awards as of the close of the Merger.

Pushdown accounting was applied to Cleco, and accordingly, the Cleco consolidated assets acquired and liabilities assumed were recorded on April 13, 2016, at their fair values as follows:

Purchase Price Allocation
(THOUSANDS)	AT APR. 13, 2016
Current assets	$	455,016
Property, plant, and equipment, net	3,432,144
Goodwill	1,490,797
Other long-term assets	1,023,487
Less
Current liabilities	228,515
Net deferred income tax liabilities	1,059,939
Other deferred credits	279,379
Long-term debt, net	1,470,126
Total purchase price	$	3,363,485

Cleco Power’s assets and liabilities were recorded at historical cost since Cleco did not elect pushdown accounting at the Cleco Power level.

The following table presents the fair value adjustments to Cleco’s balance sheet and recognition of goodwill:

(THOUSANDS)	AT APR. 13, 2016
Property, plant, and equipment	$	(1,334,932	)
Accumulated depreciation	$	(1,565,776	)
Goodwill	$	1,490,797
Intangible assets	$	91,826
Regulatory assets	$	250,409
Deferred income tax liabilities	$	126,853
Other deferred credits	$	21,175
Long-term debt	$	198,599

Most of the carrying values of Cleco’s assets and liabilities were determined to be stated at fair value at the Merger date, considering that most of these assets are subject to regulation by the LPSC and FERC. Under such regulation, rates charged to customers are established by a regulator to provide for recovery of costs and a fair return on rate base and are generally measured at historical cost. As such, a market participant would not expect to recover any more or less than the carrying value of the assets. Prior to the Merger, the Coughlin step-up value was not recorded on Cleco’s Condensed Consolidated Balance Sheet due to the accounting treatment for the transfer of that asset in March 2014. However, the recovery of the step-up value of the Coughlin asset was approved by the LPSC for recovery in base rates, including a return on rate base. On the date of the Merger, the step-up value for the Coughlin asset was recognized on Cleco’s Condensed Consolidated Balance Sheet since Cleco Power is able to earn a return on and recover these costs from its customers. The beginning balance of fixed depreciable assets was shown net at the date of the Merger, as no accumulated depreciation existed on the date of the Merger.

The excess of the purchase price over the estimated fair value of assets acquired and the liabilities assumed was $1.49 billion, which was recognized as goodwill by Cleco Holdings at the Merger date. The goodwill represents the potential long-term return of Cleco to its member. Management has assigned goodwill to Cleco’s reportable segment, Cleco Power.

A fair value adjustment was recorded on Cleco’s Condensed Consolidated Balance Sheet to reflect the valuation of the Cleco trade name. This adjustment is included in Intangible assets on Cleco’s Condensed Consolidated Balance Sheet. The valuation of the trade name was estimated by applying the relief-from-royalty method under the income approach. This valuation method is based on the premise that, in lieu of ownership of the asset, a company would be willing to pay a royalty to a third-party for the use of that asset. The owner of the asset is spared this cost, and the value of the asset is estimated by the cost savings. The projected revenue attributed to the trade name was based on projections of the value of Cleco’s wholesale contracts. The trade name is being amortized over 20 years. The amortization of the Cleco trade name is included in Depreciation and amortization on Cleco’s Condensed Consolidated Statement of Income.

On the date of the Merger, fair value adjustments were recorded on Cleco’s Condensed Consolidated Balance Sheet for the difference between the contract price and the market price of long-term wholesale power supply agreements. These adjustments are classified as Intangible assets on Cleco’s Condensed Consolidated Balance Sheet. The valuation of the power supply agreements was estimated using the income approach. The income approach is based upon discounted projected future cash flows associated with the underlying contracts. The intangible assets for the power supply agreements are being amortized over the remaining term of each applicable contract. The amortization of the power supply agreements is included in Electric operations on Cleco’s Condensed Consolidated Statement of Income.

The net increase in deferred tax liabilities on Cleco’s Condensed Consolidated Balance Sheet represents the differences between the assigned fair values of assets acquired and their related income tax basis, net of a deferred tax asset representing the net operating loss carryforward that will be utilized in future periods. As the underlying asset assigned fair values are amortized, the related deferred tax liabilities will be included in income tax expense. Goodwill is not deductible for income tax purposes; therefore, no deferred income tax assets or liabilities were recognized for goodwill.

Other fair value adjustments were recorded for long-term debt, postretirement benefit remeasurements and deferred losses, and interest rate derivative settlement gains and losses. These fair value adjustments are subject to rate regulation, but do not earn a return. In these instances, a corresponding regulatory asset was established, as the underlying utility asset or liability amounts are recoverable from or refundable to customers at historical cost through the rate setting process. These regulatory assets established to offset fair value adjustments are amortized in amounts and over time frames consistent with the realization or settlement of the fair value adjustments.

The valuations performed in the second quarter of 2016 to estimate the fair value of assets acquired and liabilities assumed were considered preliminary as a result of the short time period between the closing of the Merger and the end of the second quarter of 2016. During the third quarter of 2016, valuations were performed for the valuation and assessment of the postretirement benefit plans as of April 13, 2016, and the economic useful life of the Cleco trade name. Cleco completed its evaluation and determination of the fair value of certain assets and liabilities acquired as of December 31, 2016. There were no adjustments to those amounts during the nine months ended September 30, 2017. While management believes the positions reflected on the income tax returns are reasonable, the returns have not been audited by the applicable taxing authorities.

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Recent Authoritative Guidance

9 Months Ended

Sep. 30, 2017

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 May 2014, FASB amended the accounting guidance for revenue recognition. The amended guidance affects entities that enter into contracts for the transfer of non-financial 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. Under the new guidance, an entity must identify the performance obligations in a contract and the transaction price, and allocate the price to specific performance obligations to recognize the revenue when the obligation is completed. The amendments in this update also require extensive disclosure of sufficient information to allow users to understand the nature, amount, timing, and uncertainty of revenue and cash flow arising from contracts. Additional disclosure requirements include disaggregated revenue, reconciliation of contract balances, the entity’s performance obligations, significant judgments used, costs to obtain or fulfill a contract and the use of practical expedients. The standard will be effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Reporting entities have the option of using either a full retrospective or a modified retrospective approach. Under the full retrospective approach, companies will apply rules to contracts in all reporting periods presented, subject to certain allowable exceptions. Under the modified retrospective approach, companies will apply the rules to all contracts existing as of January 1, 2018, recognizing in beginning retained earnings an adjustment for the cumulative effect of the change and providing additional disclosures comparing results to previous rules. Cleco intends to implement the amended guidance in January 2018 using the modified retrospective approach.

Upon initial evaluation, key changes in the standard that management is assessing for potential areas of impact include accounting for contract modifications, contracts with pricing provisions that may require it to recognize revenue at prices other than the contract price (e.g., straight-line or estimated future market prices), and accounting for alternative revenue programs. Management has not identified any impacts that would have a material impact on the results of operations, financial condition, or cash flows of the Registrants. Management expects most of Cleco’s revenue to be in scope of the new guidance. The majority of sales, including energy provided to residential customers, are from tariff offerings that provide electricity supplied and billed in that period. As such, management does not expect that there will be a significant shift in the timing or pattern of revenue recognition for such sales. Management is evaluating other revenue streams, including long-term contracts with industrial and wholesale customers. Management will continue to evaluate the impact of this guidance, including any additional clarifying amendments issued during implementation. Management is finalizing the design and implementation of controls related to the new standard.

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. 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 August 2016, FASB amended the guidance for certain cash flow issues with the objective of reducing existing diversity in practice. This guidance affects the cash flow classification related to certain types of transactions including debt, contingent consideration, proceeds from the settlement of insurance claims, and distributions from equity method investees. The adoption of this guidance is effective for fiscal years beginning after December 15, 2017, including interim periods within those years. This amendment should be applied using a retrospective transition method to each period presented. This guidance will impact the presentation of the cash flow statement, but will not have an impact on the results of operations or financial condition of the Registrants.

In October 2016, FASB amended the income tax guidance related to intra-entity transfers of assets other than inventory. Current GAAP prohibits the recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party. This new guidance states that an entity should recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant 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 flow 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 is effective for fiscal years beginning after December 15, 2017, including interim periods within those years. This amendment should be applied using a retrospective transition method to each period presented. This guidance will impact the presentation of the cash flow statement, but will not have an impact on the results of operations or financial condition of the Registrants.

In January 2017, FASB issued amendments to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In January 2017, FASB amended the accounting guidance to simplify the measurement of a goodwill impairment loss. The amended guidance eliminates step two of the goodwill impairment test, which requires a hypothetical purchase price allocation to measure goodwill impairment. Under the new guidance, a goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2019, including interim periods within those years. Early adoption is permitted. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

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. The non-service cost components that are no longer eligible for capitalization under GAAP will be presented as regulatory assets. The adoption of this guidance is effective for annual periods beginning after December 15, 2017, including interim periods within those years. This amendment should be applied retrospectively for the presentation of the service cost in the income statement while the capitalization of the service cost should be applied prospectively. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In May 2017, FASB amended guidance related to service concession arrangements. The amendment clarifies that the grantor, rather than the third-party users, is the customer of the operation services in all cases for service concession arrangements. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In August 2017, FASB amended guidance related to derivatives and hedging. The amendment broadens the financial and non-financial hedging strategies that will be eligible for hedge accounting. The new guidance also changes how a company tests hedging strategies for effectiveness. 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 does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

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Regulatory Assets and Liabilities

9 Months Ended

Sep. 30, 2017

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 SEPT. 30, 2017		AT DEC. 31, 2016
Regulatory assets – deferred taxes, net	$	240,431	$	237,449
Mining costs	4,461		6,372
Interest costs	4,590		4,860
AROs	2,590		2,096
Postretirement costs	137,815		145,268
Tree trimming costs	6,801		5,549
Training costs	6,591		6,708
Surcredits, net	3,084		5,876
AMI deferred revenue requirement	4,363		4,772
Emergency declarations	3,976		—
Production operations and maintenance expenses	9,656		13,999
AFUDC equity gross-up	70,046		70,423
Acadia Unit 1 acquisition costs	2,362		2,442
Financing costs	8,385		8,663
Biomass costs	—		18
MISO integration costs	702		1,404
Coughlin transaction costs	976		999
Corporate franchise tax	968		1,308
MATS costs	3,846		4,270
Other	713		710
Total regulatory assets	271,925		285,737
Accumulated deferred fuel	21,057		20,787
Total regulatory assets, net	$	533,413	$	543,973

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

(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Total Cleco Power regulatory assets, net	$	533,413	$	543,973
Cleco Holdings’ Merger adjustments (1)
Fair value of long-term debt	149,256		155,776
Postretirement costs	21,872		23,362
Financing costs	8,708		8,966
Debt issuance costs	6,768		7,606
Total Cleco regulatory assets, net	$	720,017	$	739,683

⁽¹⁾ Cleco Holdings’ regulatory assets include acquisition accounting adjustments as a result

of the Merger.

Emergency Declarations

In August 2016, the LPSC issued emergency declaration executive orders following flooding events in south Louisiana which prohibited public utilities from disconnecting or charging late fees to customers for non-payment in affected parishes. In January 2017, the LPSC issued an order terminating those executive orders effective March 1, 2017. The January 2017 order also provided that public utilities were entitled to formally petition the LPSC to recover lost revenues as a result of the executive orders issued in August 2016. Beginning July 2017, Cleco Power’s lost revenues are being recovered and amortized over a three-year period.

Cleco Holdings’ Merger Adjustments

As a result of the Merger, Cleco implemented acquisition accounting, which eliminated AOCI at the Cleco consolidated level on the date of the Merger. Cleco will continue to recover expenses related to certain postretirement costs; therefore, Cleco recognized a regulatory asset based on its determination that these costs can continue to be collected from customers. These costs are being amortized to Other operations expense over the average remaining service period of participating employees. Cleco will also continue to recover financing costs associated with the settlement of two treasury rate locks and a forward starting swap contract that were previously recognized in AOCI. Additionally, as a result of the Merger, a regulatory asset was recorded for debt issuance costs that were eliminated at Cleco and a regulatory asset was recorded for the difference between the carrying value and the fair value of long-term debt. These regulatory assets are being amortized over the terms of the related debt issuances. On March 1, 2017, Cleco completed the repayment of the first of two tranches of its Cleco Katrina/Rita storm recovery bonds issued in March 2008. As a result, the fair value adjustments for the redeemed long-term debt and the related unamortized debt issuance cost of $0.7 million on Cleco’s Condensed Consolidated Balance Sheet were derecognized. The offset was to the respective regulatory assets.

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Fair Value Accounting

9 Months Ended

Sep. 30, 2017

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 September 30, 2017, and December 31, 2016, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, short-term debt, and accounts payable approximate fair value because of their short-term nature. Cleco applies the provisions of the fair value measurement standard to its non-recurring, non-financial measurements including business combinations as well as impairment related to goodwill and other long-lived assets.

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

Cleco
	AT SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,743,987	$	2,831,805	$	2,768,149	$	2,754,518

* The carrying value of long-term debt excludes deferred issuance costs of $11.2 million and $11.7 million at September 30, 2017, and December 31, 2016, respectively.

Cleco Power
	AT SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,244,731	$	1,428,761	$	1,262,373	$	1,418,693

* The carrying value of long-term debt excludes deferred issuance costs of $8.6 million and $9.4 million at September 30, 2017, and December 31, 2016, 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 USING:
(THOUSANDS)	AT SEPT. 30, 2017		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2016		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	$	35,117	$	—	$	35,117	$	—	$	66,410	$	—	$	66,410	$	—
FTRs	13,425		—		—		13,425		7,884		—		—		7,884
Total assets	$	48,542	$	—	$	35,117	$	13,425	$	74,294	$	—	$	66,410	$	7,884
Liability description
FTRs	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201
Total liabilities	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201

Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2017		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2016		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	$	33,796	$	—	$	33,796	$	—	$	65,089	$	—	$	65,089	$	—
FTRs	13,425		—		—		13,425		7,884		—		—		7,884
Total assets	$	47,221	$	—	$	33,796	$	13,425	$	72,973	$	—	$	65,089	$	7,884
Liability description
FTRs	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201
Total liabilities	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201

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

Cleco
							SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED SEPT. 30, 2017			FOR THE THREE MONTHS ENDED SEPT. 30, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Beginning balance	$	17,943		$	13,618		$	7,683		$	3,458		$	7,398
Unrealized gains (losses)*	1,591			1,840			(791		)	2,529			(1,031		)
Purchases	419			164			23,537			12,772			2,070
Settlements	(7,066		)	(6,046		)	(17,542		)	(9,183		)	(4,979		)
Ending balance	$	12,887		$	9,576		$	12,887		$	9,576		$	3,458
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet.

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016			2017			2016
Beginning balance	$	17,943		$	13,618		$	7,683		$	7,398
Unrealized gains (losses)*	1,591			1,840			(791		)	1,498
Purchases	419			164			23,537			14,842
Settlements	(7,066		)	(6,046		)	(17,542		)	(14,162		)
Ending balance	$	12,887		$	9,576		$	12,887		$	9,576
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheet.

The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions as of September 30, 2017, and December 31, 2016:

	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW			HIGH
FTRs at Sept. 30, 2017	$	13,425	$	538	RTO auction pricing	FTR price - per MWh	$	(3.07	)	$	5.87
FTRs at Dec. 31, 2016	$	7,884	$	201	RTO auction pricing	FTR price - per MWh	$	(3.61	)	$	6.04

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 September 30, 2017, 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 $1.8 million, $8.9 million, and $24.4 million, respectively, at September 30, 2017, and $20.0 million, $23.1 million, and $23.3 million, respectively, at December 31, 2016. 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 $0.5 million, $8.9 million, and $24.4 million, respectively, at September 30, 2017, and $18.7 million, $23.1 million, and $23.3 million, respectively, at December 31, 2016. 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 are 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 nine months ended September 30, 2017, and the year ended December 31, 2016, 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 September 30, 2017, and December 31, 2016:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT SEPT. 30, 2017		AT DEC. 31, 2016
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	13,425	$	7,884
Current	Energy risk management liabilities	538		201
Commodity-related contracts, net		$	12,887	$	7,683

The following tables present the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the nine months ended September 30, 2017, and 2016:

Cleco
		AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
								SUCCESSOR						PREDECESSOR
(THOUSANDS)	DERIVATIVES LINE ITEM	FOR THE THREE MONTHS ENDED SEPT. 30, 2017			FOR THE THREE MONTHS ENDED SEPT. 30, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Commodity contracts
FTRs(1)	Electric operations	$	14,062		$	9,718		$	35,172		$	23,467		$	8,563
FTRs(1)	Power purchased for utility customers	(7,767		)	(5,066		)	(18,759		)	(11,742		)	(5,761		)
Total		$	6,295		$	4,652		$	16,413		$	11,725		$	2,802

⁽¹⁾ For the three and nine months ended September 30, 2017, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $1.6 million and $(0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the periods July 1, 2016 - September 30, 2016, January 1, 2016 - April 12, 2016, and April 13, 2016 - September 30, 2016, unrealized (losses) gains associated with FTRs not recognized in income on derivatives of $1.8 million, $(1.0) million, and 2.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

Cleco Power
		AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	DERIVATIVES LINE ITEM	2017			2016			2017			2016
Commodity contracts
FTRs(1)	Electric operations	$	14,062		$	9,718		$	35,172		$	32,030
FTRs(1)	Power purchased for utility customers	(7,767		)	(5,066		)	(18,759		)	(17,503		)
Total		$	6,295		$	4,652		$	16,413		$	14,527

⁽¹⁾ For the three and nine months ended September 30, 2017, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $1.6 million and $(0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the three and nine months ended September 30, 2016, unrealized gains associated with FTRs not recognized in income on derivatives of $1.8 million and $1.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

At September 30, 2017, and December 31, 2016, Cleco Power had no open positions hedged for natural gas. In June 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. This proposal was submitted to the LPSC on July 28, 2017. An ALJ was assigned to the docket and a status conference was held on October 3, 2017. A procedural schedule was determined and management expects a final determination in the second quarter of 2018.

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 represent rights to congestion credits or charges along a path during a given time frame for a certain MW quantity. FTRs are not designated as hedging instruments for accounting purposes. The total volume of FTRs that Cleco Power had outstanding at September 30, 2017, and December 31, 2016, was 14.4 million MWh and 9.0 million MWh, respectively.

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Debt

9 Months Ended

Sep. 30, 2017

Debt Disclosure [Abstract]

Debt

Note 6 — Debt

At September 30, 2017, Cleco and Cleco Power had $6.5 million of short-term debt outstanding under Cleco Power’s $10.0 million uncommitted line of credit, at an all-in interest rate of 2.98%. At December 31, 2016, Cleco and 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 aggregate, to support their working capital needs.

In May 2016, Cleco Holdings completed the private sale of $535.0 million aggregate principal amount of its 3.743% senior notes due May 1, 2026, and $350.0 million aggregate principal amount of its 4.973% senior notes due May 1, 2046. Cleco Holdings used the proceeds from the issuance and sale of these notes to repay a portion of the $1.35 billion Acquisition Loan Facility entered into in connection with the completion of the Merger. On April 28, 2017, Cleco Holdings completed an exchange offer for all of its then outstanding 3.743% and 4.973% senior notes, which were not registered under the Securities Act of 1933, as amended, for an equal principal amount of newly issued 3.743% senior notes due May 1, 2026, and 4.973% senior notes due May 1, 2046, that were so registered. Cleco Holdings did not receive any proceeds from the exchange offer.

On March 1, 2017, Cleco completed the repayment of the first of two tranches of its Cleco Katrina/Rita storm recovery bonds issued in March 2008. The total principal amount for both tranches was $180.6 million. The first tranche had an initial principal amount of $113.0 million at an interest rate of 4.41% and a final maturity date of March 1, 2020. As part of the early redemption on March 1, 2017, Cleco paid $1.1 million in principal and less than $0.1 million in accrued interest.

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Pension Plan and Employee Benefits

9 Months Ended

Sep. 30, 2017

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 2016 and does not expect to make any in 2017. The required contributions are driven by liability funding target percentages set by law which could cause the required contributions to be uneven among the years. The ultimate amount and timing of the contributions may be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator.

Cleco’s retirees and their dependents may be eligible to receive medical, dental, vision, and life insurance benefits (other benefits). Cleco recognizes the expected cost of these other benefits during the periods in which the benefits are earned.

The components of net periodic pension and other benefit cost for the three and nine months ended September 30, 2017, and 2016 were as follows:

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016			2017			2016
Components of periodic benefit costs
Service cost	$	2,260		$	2,229		$	314		$	380
Interest cost	5,412			5,455			372			420
Expected return on plan assets	(6,016		)	(6,001		)	—			—
Amortizations
Prior period service credit	(18		)	(18		)	—			—
Net loss (gain)	2,502			3,365			(32		)	—
Net periodic benefit cost	$	4,140		$	5,030		$	654		$	800

	PENSION BENEFITS									OTHER BENEFITS
	SUCCESSOR						PREDECESSOR			SUCCESSOR					PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
Components of periodic benefit costs
Service cost	$	6,779		$	4,122		$	2,563		$	1,084		$	709	$	431
Interest cost	16,235			10,124			6,242			1,176			784		476
Expected return on plan assets	(18,048		)	(11,195		)	(6,812		)	—			—		—
Amortizations
Prior period service (credit) cost	(53		)	(33		)	(20		)	—			—		34
Net loss (gain)	7,506			5,211			2,798			(37		)	—		181
Net periodic benefit cost	$	12,419		$	8,229		$	4,771		$	2,223		$	1,493	$	1,122

Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three months ended September 30, 2017, and 2016 was $0.5 million and $0.4 million, respectively. The amount for the predecessor period January 1, 2016, through April 12, 2016, was $0.5 million. The expense for the successor periods for the nine months ended September 30, 2017, and April 13, 2016, through September 30, 2016, was $1.4 million and $0.8 million, respectively.

Cleco Holdings is the plan sponsor for the other benefit plans. There are no assets set aside in a trust and the liabilities are reported on the individual subsidiaries’ financial statements. The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2017, was $0.8 million and $2.5 million, respectively. The amounts for the three and nine months ended September 30, 2016, were also $0.8 million and $2.5 million, respectively. The current and non-current portions of the other benefits liability for Cleco and Cleco Power at September 30, 2017, and December 31, 2016, were as follows:

Cleco
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	3,854	$	3,854
Non-current	$	39,296	$	40,196

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	3,345	$	3,345
Non-current	$	34,147	$	34,892

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 current executive officers’ SERP benefits will be 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 year 2016 and will have their annual bonuses set at target rather than actual awards for the year 2017 for the average incentive award portion of their SERP benefit calculation. A third executive officer’s SERP calculation will use a fixed salary amount for 2017 and will exclude any compensation exceeding this amount. Management will review current market trends as it evaluates Cleco’s future compensation strategy. Cleco does not fund the SERP liability, but instead pays for current benefits out of the general funds available. Cleco Power has formed a rabbi trust. The life insurance policies issued on SERP participants designate the rabbi trust as the beneficiary. Market conditions could have a significant impact on the cash surrender value of the life insurance policies. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ death benefits, as well as future SERP payments. However, because SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. All SERP benefits are paid out of the general cash available of the respective companies that employed the officer. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator.

The components of net periodic benefit cost related to SERP for the three and nine months ended September 30, 2017, and 2016, were as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016
Components of periodic benefit costs
Service cost	$	123		$	213
Interest cost	810			839
Amortizations
Prior period service credit	(57		)	(9		)
Net loss	536			511
Total benefit cost	$	1,412		$	1,554

	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Components of periodic benefit costs
Service cost	$	370		$	277		$	702
Interest cost	2,430			1,543			900
Amortizations
Prior period service (credit) cost	(124		)	(42		)	17
Net loss	1,560			1,120			574
Net periodic benefit cost	4,236			2,898			2,193
Curtailment charge	—			—			3,602
Special/contractual termination benefits	315			—			3,222
Total benefit cost	$	4,551		$	2,898		$	9,017

There was a remeasurement of SERP on March 30, 2017, to reflect a special termination benefit resulting from an executive officer’s separation agreement. On the date of the remeasurement, the discount rate decreased from 4.22% to 4.08%. This remeasurement resulted in a special termination benefit for the executive officer of $0.3 million.

There was a remeasurement of SERP at April 13, 2016, to reflect change in control benefits as a result of the Merger. On the date of the remeasurement, the discount rate decreased from 4.60% to 4.15%. This remeasurement resulted in a $3.6 million curtailment charge and $3.2 million of special/contractual termination benefits. The curtailments and special/contractual termination benefits are included in Merger transaction and commitment costs on Cleco’s Consolidated Statements of Income. There was an additional remeasurement of SERP at August 31, 2016, to reflect changes to the plan relating to three executive officers’ SERP benefits being capped as of December 31, 2017, with regard to final compensation. On the date of the remeasurement, the discount rate decreased from 4.15% to 3.47%.

The total expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income was $0.3 million and $0.9 million for the three and nine months ended September 30, 2017, respectively, compared to $0.3 million and $1.1 million for the three and nine months ended September 30, 2016, respectively.

Liabilities relating to SERP are reported on the individual subsidiaries’ financial statements. The current and non-current portions of the SERP liability for Cleco and Cleco Power at September 30, 2017, and December 31, 2016, were as follows:

Cleco
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	4,431	$	4,308
Non-current	$	76,870	$	73,738

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	939	$	885
Non-current	$	15,999	$	15,145

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 nine monthsended September 30, 2017, and 2016, was as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016
401(k) Plan expense	$	1,386	$	1,331

	SUCCESSOR				PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
401(k) Plan expense	$	4,259	$	2,440	$	1,593

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and nine months ended September 30, 2017, and 2016, was as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016
401(k) Plan expense	$	234	$	204

	SUCCESSOR				PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
401(k) Plan expense	$	710	$	378	$	319

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Income Taxes

9 Months Ended

Sep. 30, 2017

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 nine months ended September 30, 2017, and 2016:

Cleco
					SUCCESSOR				PREDECESSOR
	FOR THE THREE MONTHS ENDED SEPT. 30, 2017		FOR THE THREE MONTHS ENDED SEPT. 30, 2016		FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
Effective tax rate	33.7	%	37.4	%	35.5	%	40.3	%	(704.9	)%

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
	2017		2016		2017		2016
Effective tax rate	35.4	%	35.9	%	36.8	%	19.5	%

For the successor periods, the effective income tax rates for Cleco were different than the federal statutory rate primarily due to permanent tax differences, the flowthrough of state tax benefits, including AFUDC equity, benefits delivered from Cleco’s investment in the NMTC Fund, and state tax expense.

For the predecessor period, the effective income tax rates for Cleco were different than the federal statutory rate primarily due to a significant portion of the merger costs not being deductible, the flowthrough of state tax benefits, including AFUDC equity, benefits delivered from Cleco’s investment in the NMTC Fund, and state tax expense.

For the three and nine months ended September 30, 2017, and 2016, the effective income tax rate for Cleco Power was different than the federal statutory rate primarily due to 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 September 30, 2017, and December 31, 2016, Cleco and Cleco Power had no interest payable related to uncertain tax positions. For the nine months ended September 30, 2017, and 2016, Cleco and Cleco Power had no interest expense related to uncertain tax positions.

At September 30, 2017, Cleco had no liability for uncertain tax positions. Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of September 30, 2017, 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 2013, 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 2017 tax year.

The state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2014 and 2015.

Cleco classifies income tax penalties as a component of other expense. For the nine months ended September 30, 2017, and 2016, no penalties were recognized.

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Disclosures about Segments

9 Months Ended

Sep. 30, 2017

Segment Reporting [Abstract]

Disclosures about Segments

Note 9 — Disclosures about Segments

Cleco’s reportable segment is based on its method of internal reporting, which disaggregates business units by its first-tier subsidiary.

Cleco Power, the reportable segment, engages in business activities from which it earns revenue and incurs expenses. Segment managers report periodically to Cleco’s CEO with discrete financial information and, at least quarterly, present discrete financial information to Cleco and Cleco Power’s Boards of Managers. The reportable segment prepares budgets that are presented to and approved by Cleco and Cleco Power’s Boards of Managers. The column shown as Other in the chart below includes the holding company, a shared services subsidiary, two transmission interconnection facility subsidiaries, and an investment subsidiary.

The financial results of Cleco’s segment 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 SEPT. 30,
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	320,009		$	(2,420	)	$	—		$	317,589
Other operations	20,768			514			—			21,282
Electric customer credits	(372		)	—			—			(372		)
Affiliate revenue	209			13,517			(13,726		)	—
Operating revenue, net	$	340,614		$	11,611		$	(13,726	)	$	338,499
Depreciation and amortization	$	40,049		$	2,179		$	—		$	42,228
Merger transaction and commitment costs	$	—		$	185		$	—		$	185
Interest charges	$	17,141		$	13,331		$	(10	)	$	30,462
Interest income	$	332		$	31		$	(9	)	$	354
Federal and state income tax expense (benefit)	$	30,092		$	(7,038	)	$	—		$	23,054
Net income (loss)	$	54,852		$	(9,548	)	$	—		$	45,304

2016 (THOUSANDS)	CLECO POWER		OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	326,281	$	(2,574	)	$	—		$	323,707
Other operations	18,460		517			(1		)	18,976
Electric customer credits	177		—			—			177
Affiliate revenue	213		13,060			(13,273		)	—
Operating revenue, net	$	345,131	$	11,003		$	(13,274	)	$	342,860
Depreciation and amortization	$	40,353	$	2,182		$	—		$	42,535
Merger transaction and commitment costs	$	—	$	1,869		$	—		$	1,869
Interest charges	$	19,177	$	12,709		$	(28	)	$	31,858
Interest income	$	264	$	82		$	(28	)	$	318
Federal and state income tax expense (benefit)	$	29,427	$	(5,728	)	$	1		$	23,700
Net income (loss)	$	52,572	$	(12,952	)	$	1		$	39,621

SEGMENT INFORMATION FOR THE NINE MONTHS ENDED SEPT. 30,
	SUCCESSOR
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	847,417		$	(8,337	)	$	—		$	839,080
Other operations	58,083			1,544			—			59,627
Electric customer credits	(1,045		)	—			—			(1,045		)
Affiliate revenue	649			41,882			(42,531		)	—
Operating revenue, net	$	905,104		$	35,089		$	(42,531	)	$	897,662
Depreciation and amortization	$	118,280		$	6,351		$	(1	)	$	124,630
Merger transaction and commitment costs	$	—		$	187		$	—		$	187
Interest charges	$	52,654		$	40,297		$	(151	)	$	92,800
Interest income	$	926		$	271		$	(151	)	$	1,046
Federal and state income tax expense (benefit)	$	63,010		$	(20,629	)	$	—		$	42,381
Net income (loss)	$	108,439		$	(31,398	)	$	—		$	77,041
Additions to property, plant, and equipment	$	183,604		$	2,005		$	—		$	185,609
Equity investment in investees (1)	$	18,172		$	—		$	—		$	18,172
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,822,302		$	592,681		$	(17,282	)	$	6,397,701
(1) Balances as of September 30, 2017

	SUCCESSOR APR. 13, 2016 - SEPT. 30, 2016												PREDECESSOR JAN. 1, 2016 - APR. 12, 2016
2016 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED			CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	558,439		$	(4,805	)	$	—		$	553,634		$	281,154		$	—		$	—		$	281,154
Other operations	32,145			965			—			33,110			18,493			587			—			19,080
Electric customer credits	(381		)	—			—			(381		)	(364		)	—			—			(364		)
Affiliate revenue	406			23,823			(24,229		)	—			263			15,024			(15,287		)	—
Operating revenue, net	$	590,609		$	19,983		$	(24,229	)	$	586,363		$	299,546		$	15,611		$	(15,287	)	$	299,870
Depreciation and amortization	$	71,498		$	5,198		$	(1	)	$	76,695		$	43,698		$	377		$	1		$	44,076
Merger transaction and commitment costs	$	151,501		$	21,671		$	—		$	173,172		$	—		$	34,928		$	(16	)	$	34,912
Interest charges	$	35,937		$	22,430		$	(44	)	$	58,323		$	21,840		$	295		$	(12	)	$	22,123
Interest income	$	382		$	177		$	(44	)	$	515		$	208		$	69		$	(12	)	$	265
Federal and state income tax (benefit) expense	$	(10,028	)	$	(18,474	)	$	—		$	(28,502	)	$	12,993		$	(9,525	)	$	—		$	3,468
Net (loss) income	$	(9,326	)	$	(32,968	)	$	—		$	(42,294	)	$	21,548		$	(25,508	)	$	—		$	(3,960	)
Additions to property, plant, and equipment	$	102,284		$	393		$	—		$	102,677		$	42,353		$	39		$	—		$	42,392
Equity investment in investees (1)	$	18,672		$	—		$	—		$	18,672
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,758,245		$	614,959		$	(30,060	)	$	6,343,144
(1) Balances as of December 31, 2016

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Regulation and Rates

9 Months Ended

Sep. 30, 2017

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. 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.

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.

On February 13, 2017, $1.2 million of refunds relating to the first complaint were submitted to MISO. As ofSeptember 30, 2017, Cleco Power had$2.0 millionaccrued 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, 2016, Cleco Power filed its monitoring report for the 12-month period ended June 30, 2016, which indicated that no refund was due as a result of the FRP and $0.3 million was due as a result of the cost of service savings from the Merger Commitments. On June 28, 2017, the LPSC approved the 2016 FRP monitoring report which confirmed no earnings-related refund. The $0.3 million cost of service savings were refunded on customer bills in September 2017. 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. As of September 30, 2017, Cleco Power had $1.5 million accrued for the cost of service savings refund.

Merger Commitments

On March 28, 2016, the LPSC approved the Merger. The LPSC’s written order approving the Merger was issued on April 7, 2016. Approval of the Merger was conditioned upon certain commitments, including $136.0 million of customer rate credits. On April 28, 2016, the LPSC voted to issue credits equally to eligible customers with service as of June 30, 2016, beginning in July 2016. As of September 30, 2017, Cleco Power had issued $130.0 million of customer rate credits. Also included in the Merger Commitments were $2.5 million of contributions for economic development for Louisiana state and local organizations to be disbursed over five years, an additional $7.0 million one-time contribution for economic development in Cleco Power’s service territory to be administered by the LED, and $6.0 million of charitable contributions to be disbursed over five years. In December 2016, the $7.0 million one-time contribution was paid to the LED.

In addition, the Merger Commitments included $1.2 million of annual estimated cost of service savings expected as a result of the Merger. The cost of service savings are not subject to the target ROE or any sharing mechanism in the current FRP and will continue until Cleco Power’s anticipated new rates begin on July 1, 2020. The cost of service savings are included in the annual monitoring reports and are refunded to customers annually. A report on the status of the Merger Commitments must be filed annually by October 31 for the 12-month period ended June 30. On October 31, 2016, Cleco Power filed the annual Merger Commitment status report for the period ended June 30, 2016. On October 31, 2017, Cleco Power filed the annual Merger Commitment status report for the period ended June 30, 2017. For more information on the cost of service savings, see “— FRP.”

SSR

In September 2016, Cleco Power filed an Attachment Y with MISO requesting retirement of Teche Unit 3 effective April 1, 2017. MISO conducted a study which determined the proposed retirement of Teche Unit 3 would result in violations of specific applicable reliability standards for which no mitigation is available. As a result, MISO designated Teche Unit 3 as an SSR unit until such time that an appropriate alternative solution can be implemented to mitigate reliability issues. One mitigating factor that has been identified is Cleco Power’s Terrebonne to Bayou Vista Transmission project, which is expected to be complete by the third quarter of 2018. Cleco Power has a 12-month SSR Agreement for the period April 1, 2017, to March 31, 2018. During this time, Cleco Power will continue to operate Teche Unit 3. Cleco Power has filed with FERC for its approval to collect $20.3 million annually in SSR payments from MISO which includes 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 Agreement. At the end of the agreement, 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 September 30, 2017, Cleco Power had $2.2 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 next settlement conference is scheduled for November 16, 2017. Cleco Power is unable to determine when a binding FERC order will be issued. Also 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. In the first quarter of 2018, another study is expected to be performed by MISO to determine if an SSR Agreement will be needed after March 31, 2018. 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.

Other

In April 2016, the LPSC issued Docket No. R-34026 to investigate double leveraging issues for all LPSC-jurisdictional utilities whereby double leveraging is utilized to fund a utility’s capital structure, and to consider whether any costs associated with such double leveraging should be included in the rates paid by the utility’s retail customers. Cleco Power filed a motion to intervene in this proceeding along with other Louisiana utilities. In April 2016, the LPSC also issued Docket No. R-34029 to investigate tax structure issues for all LPSC-jurisdictional utilities to consider whether only the state and federal taxes included in a utility’s retail rate will be those that do not exceed the utility’s share of the actual taxes paid to those federal and state taxing authorities. Cleco Power filed a motion to intervene in this proceeding along with other Louisiana utilities. In October 2016, Cleco received the first set of data requests from the LPSC Staff for each of the above mentioned dockets. Cleco has filed responses to the non-confidential requests and is waiting on the completion of a confidentiality agreement to respond to the confidential requests. Cleco is unable to determine if or when the completion of this confidentiality agreement will occur.

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Variable Interest Entities

9 Months Ended

Sep. 30, 2017

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 September 30, 2017, consisted of its equity investment of $18.2 million. In June 2017, Cleco Power received $0.5 million from Oxbow as a return of investment.

During the first quarter of 2017, the transition from the Dolet Hills mine to the Oxbow mine commenced. This transition was completed in July 2017.

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

INCEPTION TO DATE (THOUSANDS)	AT SEPT. 30, 2017			AT DEC. 31, 2016
Purchase price	$	12,873		$	12,873
Cash contributions	6,399			6,399
Dividends	(1,100		)	(600		)
Total equity investment in investee	$	18,172		$	18,672

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

(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Oxbow’s net assets/liabilities	$	36,344	$	37,345
Cleco Power’s 50% equity	$	18,172	$	18,672
Cleco Power’s maximum exposure to loss	$	18,172	$	18,672

The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016		2017		2016
Operating revenue	$	392	$	1,034	$	1,997	$	4,661
Operating expenses	392		1,034		1,997		4,661
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

9 Months Ended

Sep. 30, 2017

Commitments and Contingencies Disclosure [Abstract]

Commitments Contingencies and 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 polychlorinated biphenyl (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, 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).

On November 14, 2014, the plaintiff in the Braunstein action moved for a dismissal of the action without prejudice, and that motion was granted on November 19, 2014. On December 3, 2014, the Court consolidated the remaining three actions and appointed interim co-lead counsel. On December 18, 2014, the plaintiffs in the consolidated action filed a Consolidated Amended Verified Derivative and Class Action Petition for Damages and Preliminary and Permanent Injunction (the Consolidated Amended Petition). The consolidated action named Cleco Corporation, its directors, Cleco Partners, and Merger Sub as defendants. The Consolidated Amended Petition alleged, among other things, that Cleco Corporation’s directors breached their fiduciary duties to Cleco’s shareholders and grossly mismanaged Cleco by approving the Merger Agreement because it allegedly did not value Cleco adequately, failing to structure a process through which shareholder value would be maximized, engaging in self-dealing by ignoring conflicts of interest, and failing to disclose material information about the Merger. The Consolidated Amended Petition further alleged that all defendants conspired to commit the breaches of fiduciary duty. Cleco believes that the allegations of the Consolidated Amended Petition are without merit and that it has substantial meritorious defenses to the claims set forth in the Consolidated Amended Petition.

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

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

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

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

Both the Butler and Cashen actions name Cleco Corporation, its directors, Cleco Partners, Merger Sub, MIRA, bcIMC, and John Hancock Financial as defendants. The Creative Life Services action names Cleco Corporation, its directors, Cleco Partners, Merger Sub, MIRA, and Macquarie Infrastructure Partners III, L.P., as defendants. On December 11, 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. On December 23, 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. On December 30, 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. On January 23, 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. On February 5, 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.

On February 25, 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 at the Special Meeting of Shareholders held on February 26, 2015, for approval of the Merger Agreement. Following the hearing, the Court denied the plaintiffs’ motion. On June 19, 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 on July 24, 2015.

On March 21, 2016, the plaintiffs filed their Third Consolidated Amended Verified Derivative Petition for Damages and Preliminary and Permanent Injunction. On May 13, 2016, the plaintiffs filed their Fourth Verified Consolidated Amended Class Action Petition. This petition eliminated the request for preliminary and permanent injunction and also named an additional executive officer as a defendant. Cleco filed exceptions seeking dismissal of the amended Petition. A hearing was held on September 15, 2016. On September 26, 2016, the District Court granted the exceptions filed by Cleco and dismissed all claims asserted by the former shareholders. The plaintiffs appealed the District Court’s ruling to the Louisiana Third Circuit Court of Appeal. The Third Circuit Court of Appeal heard oral arguments in the case on September 21, 2017. Cleco expects a ruling by December 31, 2017. 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 for the State of Louisiana. In June 2016, the Third Circuit Court of Appeal for the State of Louisiana 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

On March 17, 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. Management believes that the case, as it relates to Cleco Power, has no merit.

The suit has been removed to federal court in Texas. Unless and until the federal court remands the case, it will stay in federal court.

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. In February 2016, the LPSC initiated an audit of Cleco Power’s fuel and purchased power expenses for the period January 2014 through December 2015. The total amount of fuel expense included in the audit was $582.6 million. On January 19, 2017, the LPSC Staff issued its audit report which recommended no disallowance of fuel costs. The report was approved by the LPSC on April 19, 2017. Cleco Power has FAC filings for January 2016 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings.

Environmental Audit

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. 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. In February 2016, the LPSC initiated an audit of Cleco Power’s environmental costs for the period November 2010 through December 2015. The total amount of environmental costs included in the audit was $81.2 million. In December 2016, the LPSC Staff issued its audit report which recommended a disallowance of environmental costs of less than $0.1 million. The report was approved by the LPSC on February 17, 2017. Cleco Power has EAC filings for January 2016 and thereafter that remain subject to audit. Management is unable to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings.

In the second quarter of 2015, Cleco Power began incurring additional environmental compliance expenses for reagents associated with compliance with 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 24, 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, on April 27, 2017, the court issued an order holding the cases in abeyance pending the EPA’s review of its supplemental finding. Oral arguments are set for November 16, 2017. These expenses are also eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC.

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.

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.

On February 13, 2017, $1.2 million of refunds relating to the first complaint were submitted to MISO. As of September 30, 2017, Cleco Power had $2.0 million accrued for a reduction to the ROE, including accrued interest. 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 September 30, 2017, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters is $4.6 million and has accrued this amount.

Off-Balance Sheet Commitments and Guarantees

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

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

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

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

On behalf of Acadia, Cleco Holdings provided guarantees and indemnifications as a result of the sales of Acadia Unit 1 to Cleco Power and Acadia Unit 2 to Entergy Louisiana in 2010 and 2011, respectively. The remaining indemnifications relate to the fundamental organizational structure of Acadia. These remaining indemnifications have no limitations as to time or maximum potential future payments. Currently, 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. Currently, 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 life of the investment, which ends in 2018. The $18.3 million difference between equity contributions and total benefits received will be recognized over the life of the NMTC Fund as net tax benefits are delivered.

Due to the right of offset, the investment and associated debt are presented in Tax credit fund investment, net, on Cleco’s Condensed Consolidated Balance Sheet. At December 31, 2016, the amount of the liability component contained in the net asset was $0.6 million, and it was paid on March 30, 2017. The amount of tax benefits delivered in excess of capital contributions as of September 30, 2017, was $11.8 million.

By using the cost method for investments, the gross investment amortization expense will be recognized over a ten-year period, which is projected to end in 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 October 2007, Cleco Power entered into an agreement with Savage Services that met the accounting definition of a capital lease for barges in order to transport petroleum coke and limestone to Madison Unit 3. In December 2012, Cleco Power entered into an amended agreement for 42 dedicated barges. The amended agreement continued to meet the accounting definition of a capital lease until its expiration on August 31, 2017. Upon expiration of the amended agreement, Cleco Power entered into a second amended agreement with Savage Services to continue use of the 42 barges. The new agreement meets the accounting definition of an operating lease and automatically renews the terms of the lease on a month-to-month basis until terminated by either party. For the three and nine months ended September 30, 2017, Cleco Power recognized $0.3 million in operating lease expense for the barges. Cleco Power is evaluating future options related to its fuel transportation agreement with Savage Services.

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 April 7, 2017, Moody’s updated its credit ratings by maintaining Cleco Holdings at Baa3 (stable) and Cleco Power at A3 (stable). On May 30, 2017, S&P affirmed Cleco Holdings’ and Cleco Power’s credit ratings at BBB- (stable) and BBB+ (stable), respectively.

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 Locational Marginal Price (LMP), which includes a component directly related to congestion on the transmission system. Pricing zones with greater transmission congestion may have a higher LMP. Physical transmission constraints present in the MISO market could increase energy costs within Cleco Power’s pricing zones. Cleco Power uses FTRs to mitigate transmission congestion risk. Changes to anticipated transmission paths may result in an unexpected increase in energy costs to Cleco Power.

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Affiliate Transactions

9 Months Ended

Sep. 30, 2017

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 SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	282	$	526	$	3	$	119
Support Group	1,262		7,767		1,402		7,071
Other (1)	1		—		1		—
Total	$	1,545	$	8,293	$	1,406	$	7,190
(1) Represents Attala and Perryville.

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Accumulated Other Comprehensive Loss

9 Months Ended

Sep. 30, 2017

Equity [Abstract]

Comprehensive Income (Loss) Note

Note 14 — 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 SEPT. 30, 2017								FOR THE NINE MONTHS ENDED SEPT. 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI			POSTRETIREMENT BENFIT NET GAIN (LOSS)			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(631	)	$	—	$	(631	)	$	1,500		$	—	$	1,500
Other comprehensive loss before reclassifications
Postretirement benefit adjustments during the period	—			—		—			(2,065		)	—		(2,065		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net gain	(44		)	—		(44		)	(110		)	—		(110		)
Net current-period other comprehensive loss	(44		)	—		(44		)	(2,175		)	—		(2,175		)
Balances, Sept. 30, 2017	$	(675	)	$	—	$	(675	)	$	(675	)	$	—	$	(675	)

	FOR THE THREE MONTHS ENDED SEPT. 30, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	—		$	—	$	—
Other comprehensive loss before reclassifications
Postretirement benefits adjustment during the period	(2,308		)	—		(2,308		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	3			—		3
Net current-period other comprehensive loss	(2,305		)	—		(2,305		)
Balances, Sept. 30, 2016	$	(2,305	)	$	—	$	(2,305	)

	FOR THE NINE MONTHS ENDED SEPT. 30, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
PREDECESSOR
Balances, beginning of period	$	(20,857	)	$	(5,728	)	$	(26,585	)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	587			—			587
Reclassification of net loss to interest charges	—			60			60
Net current-period other comprehensive income	587			60			647
Balances, Apr. 12, 2016	$	(20,270	)	$	(5,668	)	$	(25,938	)
SUCCESSOR(1)
Balances, Apr. 13, 2016	$	—		$	—		$	—
Other comprehensive loss before reclassifications
Postretirement benefits adjustment during the period	(2,308		)	—			(2,308		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	3			—			3
Net current-period other comprehensive loss	(2,305		)	—			(2,305		)
Balances, Sept. 30, 2016	$	(2,305	)	$	—		$	(2,305	)
(1) As a result of the Merger, accumulated other comprehensive income was reduced to zero on April 13, 2016, as required by acquisition accounting.

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30, 2017									FOR THE NINE MONTHS ENDED SEPT. 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	$	(8,132	)	$	(5,411	)	$	(13,543	)	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive loss before reclassifications
Postretirement benefit adjustments during the period	—			—			—			(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	167			—			167			524			—			524
Reclassification of net loss to interest charges	—			53			53			—			159			159
Net current-period other comprehensive income (loss)	167			53			220			(60		)	159			99
Balances, Sept. 30, 2017	$	(7,965	)	$	(5,358	)	$	(13,323	)	$	(7,965	)	$	(5,358	)	$	(13,323	)

	FOR THE THREE MONTHS ENDED SEPT. 30, 2016									FOR THE NINE MONTHS ENDED SEPT. 30, 2016
(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	$	(10,983	)	$	(5,622	)	$	(16,605	)	$	(11,364	)	$	(5,728	)	$	(17,092	)
Other comprehensive income before reclassifications:
Postretirement benefit adjustments during the period	2,013			—			2,013			2,013			—			2,013
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	167			—			167			548			—			548
Reclassification of net loss to interest charges	—			53			53			—			159			159
Net current-period other comprehensive income	2,180			53			2,233			2,561			159			2,720
Balances, Sept. 30, 2016	$	(8,803	)	$	(5,569	)	$	(14,372	)	$	(8,803	)	$	(5,569	)	$	(14,372	)

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Subsequent Event Subsequent Event

9 Months Ended

Sep. 30, 2017

Subsequent Events [Abstract]

Subsequent Events

Note 15 — Subsequent Event

On October 10, 2017, Cleco Power, Attala, Perryville, Entergy Louisiana, and Entergy Mississippi completed a joint filing with FERC. The filing requested approval for Cleco Power and Perryville to sell certain transmission assets to Entergy Louisiana and for Attala to sell certain transmission assets to Entergy Mississippi. The filing requested an approval date by December 18, 2017. If approved, the parties will enter into binding agreements for the sale of the assets. The parties expect completion of the agreements by the end of 2017.

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2017

Accounting Policies [Abstract]

Principles of Consolidation, Policy

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, Policy

Cleco Holdings accounted for the merger transaction by applying the acquisition method of accounting. The objective of the acquisition method is to establish a new accounting basis for the acquiree, Cleco Holdings and its subsidiaries, and requires the acquirer, Cleco Group, to recognize and measure the acquiree’s assets and liabilities at fair value as of the acquisition date. Cleco Power’s assets and liabilities were recorded at historical cost since Cleco did not elect pushdown accounting at the Cleco Power level. The financial statements and accompanying footnotes for Cleco have been segregated to present pre-merger activity as the “Predecessor” and post-merger activity as the “Successor.” The predecessor period is not comparable to the successor period.

Goodwill, Policy

Cleco conducted its 2017 annual impairment test using an August 1, 2017, measurement date. The fair value of Cleco’s reporting segment, Cleco Power, was estimated using a weighted combination of the income approach, which estimates fair value based on discounted cash flows, and the market approach, which estimates fair value based on market comparables within the utility and energy industries. Significant assumptions used in these fair value estimates include estimation of future cash flows, long-term rate of growth, the selection of comparable companies, and weighted-average cost of capital (WACC) or discount rate. Changes in these assumptions could materially affect the determination of fair value and goodwill impairment at Cleco Power.

Restricted Cash and Cash Equivalents, Policy

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 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.

Fair Value Measurements and Disclosures, Policy

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, Policy

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. In June 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. This proposal was submitted to the LPSC on July 28, 2017

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.

Stock-Based Compensation, Policy

Prior to the completion of the Merger, Cleco had two stock-based compensation plans: the ESPP and the LTIP. As a result of the completion of the Merger, both stock-based compensation plans were terminated.

Pursuant to the terms of the LTIP, certain officers, key employees, and directors of Cleco were eligible to be granted stock options, restricted stock, also known as non-vested stock, common stock equivalents, and stock appreciation rights.

As a result of the Merger on April 13, 2016, all unvested shares outstanding under the LTIP that were granted prior to January 1, 2015, vested at target and were paid out in cash to plan participants. Unvested shares that were granted during 2015 were prorated to the target amount and paid out in cash to plan participants in accordance with the terms of the Merger Agreement.

Business Combinations, Policy

Most of the carrying values of Cleco’s assets and liabilities were determined to be stated at fair value at the Merger date, considering that most of these assets are subject to regulation by the LPSC and FERC. Under such regulation, rates charged to customers are established by a regulator to provide for recovery of costs and a fair return on rate base and are generally measured at historical cost. As such, a market participant would not expect to recover any more or less than the carrying value of the assets. Prior to the Merger, the Coughlin step-up value was not recorded on Cleco’s Condensed Consolidated Balance Sheet due to the accounting treatment for the transfer of that asset in March 2014. However, the recovery of the step-up value of the Coughlin asset was approved by the LPSC for recovery in base rates, including a return on rate base. On the date of the Merger, the step-up value for the Coughlin asset was recognized on Cleco’s Condensed Consolidated Balance Sheet since Cleco Power is able to earn a return on and recover these costs from its customers. The beginning balance of fixed depreciable assets was shown net at the date of the Merger, as no accumulated depreciation existed on the date of the Merger.

The excess of the purchase price over the estimated fair value of assets acquired and the liabilities assumed was $1.49 billion, which was recognized as goodwill by Cleco Holdings at the Merger date. The goodwill represents the potential long-term return of Cleco to its member. Management has assigned goodwill to Cleco’s reportable segment, Cleco Power.

A fair value adjustment was recorded on Cleco’s Condensed Consolidated Balance Sheet to reflect the valuation of the Cleco trade name. This adjustment is included in Intangible assets on Cleco’s Condensed Consolidated Balance Sheet. The valuation of the trade name was estimated by applying the relief-from-royalty method under the income approach. This valuation method is based on the premise that, in lieu of ownership of the asset, a company would be willing to pay a royalty to a third-party for the use of that asset. The owner of the asset is spared this cost, and the value of the asset is estimated by the cost savings. The projected revenue attributed to the trade name was based on projections of the value of Cleco’s wholesale contracts. The trade name is being amortized over 20 years. The amortization of the Cleco trade name is included in Depreciation and amortization on Cleco’s Condensed Consolidated Statement of Income.

On the date of the Merger, fair value adjustments were recorded on Cleco’s Condensed Consolidated Balance Sheet for the difference between the contract price and the market price of long-term wholesale power supply agreements. These adjustments are classified as Intangible assets on Cleco’s Condensed Consolidated Balance Sheet. The valuation of the power supply agreements was estimated using the income approach. The income approach is based upon discounted projected future cash flows associated with the underlying contracts. The intangible assets for the power supply agreements are being amortized over the remaining term of each applicable contract. The amortization of the power supply agreements is included in Electric operations on Cleco’s Condensed Consolidated Statement of Income.

The net increase in deferred tax liabilities on Cleco’s Condensed Consolidated Balance Sheet represents the differences between the assigned fair values of assets acquired and their related income tax basis, net of a deferred tax asset representing the net operating loss carryforward that will be utilized in future periods. As the underlying asset assigned fair values are amortized, the related deferred tax liabilities will be included in income tax expense. Goodwill is not deductible for income tax purposes; therefore, no deferred income tax assets or liabilities were recognized for goodwill.

Other fair value adjustments were recorded for long-term debt, postretirement benefit remeasurements and deferred losses, and interest rate derivative settlement gains and losses. These fair value adjustments are subject to rate regulation, but do not earn a return. In these instances, a corresponding regulatory asset was established, as the underlying utility asset or liability amounts are recoverable from or refundable to customers at historical cost through the rate setting process. These regulatory assets established to offset fair value adjustments are amortized in amounts and over time frames consistent with the realization or settlement of the fair value adjustments.

The valuations performed in the second quarter of 2016 to estimate the fair value of assets acquired and liabilities assumed were considered preliminary as a result of the short time period between the closing of the Merger and the end of the second quarter of 2016. During the third quarter of 2016, valuations were performed for the valuation and assessment of the postretirement benefit plans as of April 13, 2016, and the economic useful life of the Cleco trade name. Cleco completed its evaluation and determination of the fair value of certain assets and liabilities acquired as of December 31, 2016. There were no adjustments to those amounts during the nine months ended September 30, 2017. While management believes the positions reflected on the income tax returns are reasonable, the returns have not been audited by the applicable taxing authorities.

As a result of the Merger, Cleco implemented acquisition accounting, which eliminated AOCI at the Cleco consolidated level on the date of the Merger. Cleco will continue to recover expenses related to certain postretirement costs; therefore, Cleco recognized a regulatory asset based on its determination that these costs can continue to be collected from customers. These costs are being amortized to Other operations expense over the average remaining service period of participating employees. Cleco will also continue to recover financing costs associated with the settlement of two treasury rate locks and a forward starting swap contract that were previously recognized in AOCI. Additionally, as a result of the Merger, a regulatory asset was recorded for debt issuance costs that were eliminated at Cleco and a regulatory asset was recorded for the difference between the carrying value and the fair value of long-term debt. These regulatory assets are being amortized over the terms of the related debt issuances.

Pushdown Accounting, Policy

Pushdown accounting was applied to Cleco, and accordingly, the Cleco consolidated assets acquired and liabilities assumed were recorded on April 13, 2016, at their fair values

Recent Authoritative Guidance, Policy

In May 2014, FASB amended the accounting guidance for revenue recognition. The amended guidance affects entities that enter into contracts for the transfer of non-financial 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. Under the new guidance, an entity must identify the performance obligations in a contract and the transaction price, and allocate the price to specific performance obligations to recognize the revenue when the obligation is completed. The amendments in this update also require extensive disclosure of sufficient information to allow users to understand the nature, amount, timing, and uncertainty of revenue and cash flow arising from contracts. Additional disclosure requirements include disaggregated revenue, reconciliation of contract balances, the entity’s performance obligations, significant judgments used, costs to obtain or fulfill a contract and the use of practical expedients. The standard will be effective for annual reporting periods beginning after December 15, 2017, including interim periods within that reporting period. Reporting entities have the option of using either a full retrospective or a modified retrospective approach. Under the full retrospective approach, companies will apply rules to contracts in all reporting periods presented, subject to certain allowable exceptions. Under the modified retrospective approach, companies will apply the rules to all contracts existing as of January 1, 2018, recognizing in beginning retained earnings an adjustment for the cumulative effect of the change and providing additional disclosures comparing results to previous rules. Cleco intends to implement the amended guidance in January 2018 using the modified retrospective approach.

Upon initial evaluation, key changes in the standard that management is assessing for potential areas of impact include accounting for contract modifications, contracts with pricing provisions that may require it to recognize revenue at prices other than the contract price (e.g., straight-line or estimated future market prices), and accounting for alternative revenue programs. Management has not identified any impacts that would have a material impact on the results of operations, financial condition, or cash flows of the Registrants. Management expects most of Cleco’s revenue to be in scope of the new guidance. The majority of sales, including energy provided to residential customers, are from tariff offerings that provide electricity supplied and billed in that period. As such, management does not expect that there will be a significant shift in the timing or pattern of revenue recognition for such sales. Management is evaluating other revenue streams, including long-term contracts with industrial and wholesale customers. Management will continue to evaluate the impact of this guidance, including any additional clarifying amendments issued during implementation. Management is finalizing the design and implementation of controls related to the new standard.

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. 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 August 2016, FASB amended the guidance for certain cash flow issues with the objective of reducing existing diversity in practice. This guidance affects the cash flow classification related to certain types of transactions including debt, contingent consideration, proceeds from the settlement of insurance claims, and distributions from equity method investees. The adoption of this guidance is effective for fiscal years beginning after December 15, 2017, including interim periods within those years. This amendment should be applied using a retrospective transition method to each period presented. This guidance will impact the presentation of the cash flow statement, but will not have an impact on the results of operations or financial condition of the Registrants.

In October 2016, FASB amended the income tax guidance related to intra-entity transfers of assets other than inventory. Current GAAP prohibits the recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party. This new guidance states that an entity should recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant 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 flow 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 is effective for fiscal years beginning after December 15, 2017, including interim periods within those years. This amendment should be applied using a retrospective transition method to each period presented. This guidance will impact the presentation of the cash flow statement, but will not have an impact on the results of operations or financial condition of the Registrants.

In January 2017, FASB issued amendments to clarify the definition of a business with the objective of adding guidance to assist entities with evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In January 2017, FASB amended the accounting guidance to simplify the measurement of a goodwill impairment loss. The amended guidance eliminates step two of the goodwill impairment test, which requires a hypothetical purchase price allocation to measure goodwill impairment. Under the new guidance, a goodwill impairment will now be the amount by which a reporting unit’s carrying value exceeds its fair value, not to exceed the carrying amount of goodwill. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2019, including interim periods within those years. Early adoption is permitted. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

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. The non-service cost components that are no longer eligible for capitalization under GAAP will be presented as regulatory assets. The adoption of this guidance is effective for annual periods beginning after December 15, 2017, including interim periods within those years. This amendment should be applied retrospectively for the presentation of the service cost in the income statement while the capitalization of the service cost should be applied prospectively. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In May 2017, FASB amended guidance related to service concession arrangements. The amendment clarifies that the grantor, rather than the third-party users, is the customer of the operation services in all cases for service concession arrangements. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim periods within those years. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

In August 2017, FASB amended guidance related to derivatives and hedging. The amendment broadens the financial and non-financial hedging strategies that will be eligible for hedge accounting. The new guidance also changes how a company tests hedging strategies for effectiveness. 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 does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants.

Regulatory Assets and Liabilities, Policy

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 and Other Postretirement Plans, Policy

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.

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.

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 current executive officers’ SERP benefits will be 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 year 2016 and will have their annual bonuses set at target rather than actual awards for the year 2017 for the average incentive award portion of their SERP benefit calculation. A third executive officer’s SERP calculation will use a fixed salary amount for 2017 and will exclude any compensation exceeding this amount. Management will review current market trends as it evaluates Cleco’s future compensation strategy. Cleco does not fund the SERP liability, but instead pays for current benefits out of the general funds available. Cleco Power has formed a rabbi trust. The life insurance policies issued on SERP participants designate the rabbi trust as the beneficiary. Market conditions could have a significant impact on the cash surrender value of the life insurance policies. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ death benefits, as well as future SERP payments. However, because SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. All SERP benefits are paid out of the general cash available of the respective companies that employed the officer. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator.

Cleco’s retirees and their dependents may be eligible to receive medical, dental, vision, and life insurance benefits (other benefits). Cleco recognizes the expected cost of these other benefits during the periods in which the benefits are earned.

Income Tax, Policy

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, Policy

The financial results of Cleco’s segment 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.

Equity Method Investments, Policy

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 Entity, Policy

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.

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Summary of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2017

Accounting Policies [Line Items]

Restricted Cash and Cash Equivalents

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

Cleco
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,798	$	9,213
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	3,876		12,671
Total current	8,874		23,084
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	17,999		17,379
Cleco Power’s charitable contributions	3,640		4,179
Cleco Power’s rate credit escrow	2,887		1,831
Total non-current	24,547		23,410
Total restricted cash and cash equivalents	$	33,421	$	46,494

Cleco Power [Member]

Accounting Policies [Line Items]

Restricted Cash and Cash Equivalents

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,798	$	9,213
Charitable contributions	1,200		1,200
Rate credit escrow	3,876		12,671
Total current	8,874		23,084
Non-current
Future storm restoration costs	17,999		17,379
Charitable contributions	3,640		4,179
Rate credit escrow	2,887		1,831
Total non-current	24,526		23,389
Total restricted cash and cash equivalents	$	33,400	$	46,473

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Business Combination (Tables)

9 Months Ended

Sep. 30, 2017

Business Combinations [Abstract]

Schedule of Business Acquisitions, by Acquisition

Pushdown accounting was applied to Cleco, and accordingly, the Cleco consolidated assets acquired and liabilities assumed were recorded on April 13, 2016, at their fair values as follows:

Purchase Price Allocation
(THOUSANDS)	AT APR. 13, 2016
Current assets	$	455,016
Property, plant, and equipment, net	3,432,144
Goodwill	1,490,797
Other long-term assets	1,023,487
Less
Current liabilities	228,515
Net deferred income tax liabilities	1,059,939
Other deferred credits	279,379
Long-term debt, net	1,470,126
Total purchase price	$	3,363,485

The following table presents the fair value adjustments to Cleco’s balance sheet and recognition of goodwill:

(THOUSANDS)	AT APR. 13, 2016
Property, plant, and equipment	$	(1,334,932	)
Accumulated depreciation	$	(1,565,776	)
Goodwill	$	1,490,797
Intangible assets	$	91,826
Regulatory assets	$	250,409
Deferred income tax liabilities	$	126,853
Other deferred credits	$	21,175
Long-term debt	$	198,599

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Regulatory Assets and Liabilities (Tables)

9 Months Ended

Sep. 30, 2017

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 SEPT. 30, 2017		AT DEC. 31, 2016
Total Cleco Power regulatory assets, net	$	533,413	$	543,973
Cleco Holdings’ Merger adjustments (1)
Fair value of long-term debt	149,256		155,776
Postretirement costs	21,872		23,362
Financing costs	8,708		8,966
Debt issuance costs	6,768		7,606
Total Cleco regulatory assets, net	$	720,017	$	739,683

⁽¹⁾ Cleco Holdings’ regulatory assets include acquisition accounting adjustments as a result

of the Merger.

Cleco Power [Member]

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 SEPT. 30, 2017		AT DEC. 31, 2016
Regulatory assets – deferred taxes, net	$	240,431	$	237,449
Mining costs	4,461		6,372
Interest costs	4,590		4,860
AROs	2,590		2,096
Postretirement costs	137,815		145,268
Tree trimming costs	6,801		5,549
Training costs	6,591		6,708
Surcredits, net	3,084		5,876
AMI deferred revenue requirement	4,363		4,772
Emergency declarations	3,976		—
Production operations and maintenance expenses	9,656		13,999
AFUDC equity gross-up	70,046		70,423
Acadia Unit 1 acquisition costs	2,362		2,442
Financing costs	8,385		8,663
Biomass costs	—		18
MISO integration costs	702		1,404
Coughlin transaction costs	976		999
Corporate franchise tax	968		1,308
MATS costs	3,846		4,270
Other	713		710
Total regulatory assets	271,925		285,737
Accumulated deferred fuel	21,057		20,787
Total regulatory assets, net	$	533,413	$	543,973

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Fair Value Accounting (Tables)

9 Months Ended

Sep. 30, 2017

Fair Value [Line Items]

Fair Value By Balance Sheet Grouping

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

Cleco
	AT SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,743,987	$	2,831,805	$	2,768,149	$	2,754,518

* The carrying value of long-term debt excludes deferred issuance costs of $11.2 million and $11.7 million at September 30, 2017, and December 31, 2016, 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 USING:
(THOUSANDS)	AT SEPT. 30, 2017		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2016		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	$	35,117	$	—	$	35,117	$	—	$	66,410	$	—	$	66,410	$	—
FTRs	13,425		—		—		13,425		7,884		—		—		7,884
Total assets	$	48,542	$	—	$	35,117	$	13,425	$	74,294	$	—	$	66,410	$	7,884
Liability description
FTRs	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201
Total liabilities	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation

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

Cleco
							SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED SEPT. 30, 2017			FOR THE THREE MONTHS ENDED SEPT. 30, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Beginning balance	$	17,943		$	13,618		$	7,683		$	3,458		$	7,398
Unrealized gains (losses)*	1,591			1,840			(791		)	2,529			(1,031		)
Purchases	419			164			23,537			12,772			2,070
Settlements	(7,066		)	(6,046		)	(17,542		)	(9,183		)	(4,979		)
Ending balance	$	12,887		$	9,576		$	12,887		$	9,576		$	3,458
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet.

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 September 30, 2017, and December 31, 2016:

	FAIR VALUE				VALUATION TECHNIQUE	SIGNIFICANT UNOBSERVABLE INPUTS	FORWARD PRICE RANGE
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	ASSETS		LIABILITIES				LOW			HIGH
FTRs at Sept. 30, 2017	$	13,425	$	538	RTO auction pricing	FTR price - per MWh	$	(3.07	)	$	5.87
FTRs at Dec. 31, 2016	$	7,884	$	201	RTO auction pricing	FTR price - per MWh	$	(3.61	)	$	6.04

Derivatives Not Designated As Hedging Instrument

Fair Value [Line Items]

Fair Value of Derivative Instruments in Statement of Financial Position

The following table presents the fair values of derivative instruments and their respective line items as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2017, and December 31, 2016:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT SEPT. 30, 2017		AT DEC. 31, 2016
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	13,425	$	7,884
Current	Energy risk management liabilities	538		201
Commodity-related contracts, net		$	12,887	$	7,683

Effect of Derivatives On Consolidated Statements of Income

The following tables present the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the nine months ended September 30, 2017, and 2016:

Cleco
		AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
								SUCCESSOR						PREDECESSOR
(THOUSANDS)	DERIVATIVES LINE ITEM	FOR THE THREE MONTHS ENDED SEPT. 30, 2017			FOR THE THREE MONTHS ENDED SEPT. 30, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Commodity contracts
FTRs(1)	Electric operations	$	14,062		$	9,718		$	35,172		$	23,467		$	8,563
FTRs(1)	Power purchased for utility customers	(7,767		)	(5,066		)	(18,759		)	(11,742		)	(5,761		)
Total		$	6,295		$	4,652		$	16,413		$	11,725		$	2,802

⁽¹⁾ For the three and nine months ended September 30, 2017, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $1.6 million and $(0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the periods July 1, 2016 - September 30, 2016, January 1, 2016 - April 12, 2016, and April 13, 2016 - September 30, 2016, unrealized (losses) gains associated with FTRs not recognized in income on derivatives of $1.8 million, $(1.0) million, and 2.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

Cleco Power [Member]

Fair Value [Line Items]

Fair Value By Balance Sheet Grouping

Cleco Power
	AT SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,244,731	$	1,428,761	$	1,262,373	$	1,418,693

* The carrying value of long-term debt excludes deferred issuance costs of $8.6 million and $9.4 million at September 30, 2017, and December 31, 2016, respectively.

Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis

Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2017		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2016		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	$	33,796	$	—	$	33,796	$	—	$	65,089	$	—	$	65,089	$	—
FTRs	13,425		—		—		13,425		7,884		—		—		7,884
Total assets	$	47,221	$	—	$	33,796	$	13,425	$	72,973	$	—	$	65,089	$	7,884
Liability description
FTRs	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201
Total liabilities	$	538	$	—	$	—	$	538	$	201	$	—	$	—	$	201

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016			2017			2016
Beginning balance	$	17,943		$	13,618		$	7,683		$	7,398
Unrealized gains (losses)*	1,591			1,840			(791		)	1,498
Purchases	419			164			23,537			14,842
Settlements	(7,066		)	(6,046		)	(17,542		)	(14,162		)
Ending balance	$	12,887		$	9,576		$	12,887		$	9,576
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheet.

Cleco Power [Member] | Derivatives Not Designated As Hedging Instrument

Fair Value [Line Items]

Effect of Derivatives On Consolidated Statements of Income

Cleco Power
		AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	DERIVATIVES LINE ITEM	2017			2016			2017			2016
Commodity contracts
FTRs(1)	Electric operations	$	14,062		$	9,718		$	35,172		$	32,030
FTRs(1)	Power purchased for utility customers	(7,767		)	(5,066		)	(18,759		)	(17,503		)
Total		$	6,295		$	4,652		$	16,413		$	14,527

⁽¹⁾ For the three and nine months ended September 30, 2017, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $1.6 million and $(0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet. For the three and nine months ended September 30, 2016, unrealized gains associated with FTRs not recognized in income on derivatives of $1.8 million and $1.5 million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

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Pension Plan and Employee Benefits (Tables)

9 Months Ended

Sep. 30, 2017

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net periodic benefit costs

The components of net periodic pension and other benefit cost for the three and nine months ended September 30, 2017, and 2016 were as follows:

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016			2017			2016
Components of periodic benefit costs
Service cost	$	2,260		$	2,229		$	314		$	380
Interest cost	5,412			5,455			372			420
Expected return on plan assets	(6,016		)	(6,001		)	—			—
Amortizations
Prior period service credit	(18		)	(18		)	—			—
Net loss (gain)	2,502			3,365			(32		)	—
Net periodic benefit cost	$	4,140		$	5,030		$	654		$	800

	PENSION BENEFITS									OTHER BENEFITS
	SUCCESSOR						PREDECESSOR			SUCCESSOR					PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016			FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
Components of periodic benefit costs
Service cost	$	6,779		$	4,122		$	2,563		$	1,084		$	709	$	431
Interest cost	16,235			10,124			6,242			1,176			784		476
Expected return on plan assets	(18,048		)	(11,195		)	(6,812		)	—			—		—
Amortizations
Prior period service (credit) cost	(53		)	(33		)	(20		)	—			—		34
Net loss (gain)	7,506			5,211			2,798			(37		)	—		181
Net periodic benefit cost	$	12,419		$	8,229		$	4,771		$	2,223		$	1,493	$	1,122

401(k) Plan expense

Cleco’s 401(k) Plan expense for the three and nine monthsended September 30, 2017, and 2016, was as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016
401(k) Plan expense	$	1,386	$	1,331

	SUCCESSOR				PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
401(k) Plan expense	$	4,259	$	2,440	$	1,593

Other Postretirement Benefits Plan [Member]

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 September 30, 2017, and December 31, 2016, were as follows:

Cleco
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	3,854	$	3,854
Non-current	$	39,296	$	40,196

SERP Benefits [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Net periodic benefit costs

The components of net periodic benefit cost related to SERP for the three and nine months ended September 30, 2017, and 2016, were as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017			2016
Components of periodic benefit costs
Service cost	$	123		$	213
Interest cost	810			839
Amortizations
Prior period service credit	(57		)	(9		)
Net loss	536			511
Total benefit cost	$	1,412		$	1,554

	SUCCESSOR						PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017			APR. 13, 2016 - SEPT. 30, 2016			JAN. 1, 2016 - APR. 12, 2016
Components of periodic benefit costs
Service cost	$	370		$	277		$	702
Interest cost	2,430			1,543			900
Amortizations
Prior period service (credit) cost	(124		)	(42		)	17
Net loss	1,560			1,120			574
Net periodic benefit cost	4,236			2,898			2,193
Curtailment charge	—			—			3,602
Special/contractual termination benefits	315			—			3,222
Total benefit cost	$	4,551		$	2,898		$	9,017

Schedule of current and non-current portions

The current and non-current portions of the SERP liability for Cleco and Cleco Power at September 30, 2017, and December 31, 2016, were as follows:

Cleco
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	4,431	$	4,308
Non-current	$	76,870	$	73,738

Other Subsidiaries [Member]

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 nine months ended September 30, 2017, and 2016, was as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016
401(k) Plan expense	$	234	$	204

	SUCCESSOR				PREDECESSOR
(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
401(k) Plan expense	$	710	$	378	$	319

Cleco Power [Member] | Other Postretirement Benefits Plan [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Schedule of current and non-current portions

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	3,345	$	3,345
Non-current	$	34,147	$	34,892

Cleco Power [Member] | SERP Benefits [Member]

Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]

Schedule of current and non-current portions

Cleco Power
(THOUSANDS)	AT SEPT. 30, 2017		AT DEC. 31, 2016
Current	$	939	$	885
Non-current	$	15,999	$	15,145

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Income Taxes (Tables)

9 Months Ended

Sep. 30, 2017

Effective Income Tax Rate [Line Items]

Effective income tax rates

The following tables summarize the effective income tax rates for Cleco and Cleco Power for the three and nine months ended September 30, 2017, and 2016:

Cleco
					SUCCESSOR				PREDECESSOR
	FOR THE THREE MONTHS ENDED SEPT. 30, 2017		FOR THE THREE MONTHS ENDED SEPT. 30, 2016		FOR THE NINE MONTHS ENDED SEPT. 30, 2017		APR. 13, 2016 - SEPT. 30, 2016		JAN. 1, 2016 - APR. 12, 2016
Effective tax rate	33.7	%	37.4	%	35.5	%	40.3	%	(704.9	)%

Cleco Power [Member]

Effective Income Tax Rate [Line Items]

Effective income tax rates

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
	2017		2016		2017		2016
Effective tax rate	35.4	%	35.9	%	36.8	%	19.5	%

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Disclosures about Segments (Tables)

9 Months Ended

Sep. 30, 2017

Segment Reporting [Abstract]

Segment Information

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED SEPT. 30,
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	320,009		$	(2,420	)	$	—		$	317,589
Other operations	20,768			514			—			21,282
Electric customer credits	(372		)	—			—			(372		)
Affiliate revenue	209			13,517			(13,726		)	—
Operating revenue, net	$	340,614		$	11,611		$	(13,726	)	$	338,499
Depreciation and amortization	$	40,049		$	2,179		$	—		$	42,228
Merger transaction and commitment costs	$	—		$	185		$	—		$	185
Interest charges	$	17,141		$	13,331		$	(10	)	$	30,462
Interest income	$	332		$	31		$	(9	)	$	354
Federal and state income tax expense (benefit)	$	30,092		$	(7,038	)	$	—		$	23,054
Net income (loss)	$	54,852		$	(9,548	)	$	—		$	45,304

2016 (THOUSANDS)	CLECO POWER		OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	326,281	$	(2,574	)	$	—		$	323,707
Other operations	18,460		517			(1		)	18,976
Electric customer credits	177		—			—			177
Affiliate revenue	213		13,060			(13,273		)	—
Operating revenue, net	$	345,131	$	11,003		$	(13,274	)	$	342,860
Depreciation and amortization	$	40,353	$	2,182		$	—		$	42,535
Merger transaction and commitment costs	$	—	$	1,869		$	—		$	1,869
Interest charges	$	19,177	$	12,709		$	(28	)	$	31,858
Interest income	$	264	$	82		$	(28	)	$	318
Federal and state income tax expense (benefit)	$	29,427	$	(5,728	)	$	1		$	23,700
Net income (loss)	$	52,572	$	(12,952	)	$	1		$	39,621

SEGMENT INFORMATION FOR THE NINE MONTHS ENDED SEPT. 30,
	SUCCESSOR
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	847,417		$	(8,337	)	$	—		$	839,080
Other operations	58,083			1,544			—			59,627
Electric customer credits	(1,045		)	—			—			(1,045		)
Affiliate revenue	649			41,882			(42,531		)	—
Operating revenue, net	$	905,104		$	35,089		$	(42,531	)	$	897,662
Depreciation and amortization	$	118,280		$	6,351		$	(1	)	$	124,630
Merger transaction and commitment costs	$	—		$	187		$	—		$	187
Interest charges	$	52,654		$	40,297		$	(151	)	$	92,800
Interest income	$	926		$	271		$	(151	)	$	1,046
Federal and state income tax expense (benefit)	$	63,010		$	(20,629	)	$	—		$	42,381
Net income (loss)	$	108,439		$	(31,398	)	$	—		$	77,041
Additions to property, plant, and equipment	$	183,604		$	2,005		$	—		$	185,609
Equity investment in investees (1)	$	18,172		$	—		$	—		$	18,172
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,822,302		$	592,681		$	(17,282	)	$	6,397,701
(1) Balances as of September 30, 2017

	SUCCESSOR APR. 13, 2016 - SEPT. 30, 2016												PREDECESSOR JAN. 1, 2016 - APR. 12, 2016
2016 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED			CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	558,439		$	(4,805	)	$	—		$	553,634		$	281,154		$	—		$	—		$	281,154
Other operations	32,145			965			—			33,110			18,493			587			—			19,080
Electric customer credits	(381		)	—			—			(381		)	(364		)	—			—			(364		)
Affiliate revenue	406			23,823			(24,229		)	—			263			15,024			(15,287		)	—
Operating revenue, net	$	590,609		$	19,983		$	(24,229	)	$	586,363		$	299,546		$	15,611		$	(15,287	)	$	299,870
Depreciation and amortization	$	71,498		$	5,198		$	(1	)	$	76,695		$	43,698		$	377		$	1		$	44,076
Merger transaction and commitment costs	$	151,501		$	21,671		$	—		$	173,172		$	—		$	34,928		$	(16	)	$	34,912
Interest charges	$	35,937		$	22,430		$	(44	)	$	58,323		$	21,840		$	295		$	(12	)	$	22,123
Interest income	$	382		$	177		$	(44	)	$	515		$	208		$	69		$	(12	)	$	265
Federal and state income tax (benefit) expense	$	(10,028	)	$	(18,474	)	$	—		$	(28,502	)	$	12,993		$	(9,525	)	$	—		$	3,468
Net (loss) income	$	(9,326	)	$	(32,968	)	$	—		$	(42,294	)	$	21,548		$	(25,508	)	$	—		$	(3,960	)
Additions to property, plant, and equipment	$	102,284		$	393		$	—		$	102,677		$	42,353		$	39		$	—		$	42,392
Equity investment in investees (1)	$	18,672		$	—		$	—		$	18,672
Goodwill (1)	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets (1)	$	5,758,245		$	614,959		$	(30,060	)	$	6,343,144
(1) Balances as of December 31, 2016

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Variable Interest Entities (Tables) - Cleco Power [Member]

9 Months Ended

Sep. 30, 2017

Variable Interest Entity [Line Items]

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 SEPT. 30, 2017		AT DEC. 31, 2016
Oxbow’s net assets/liabilities	$	36,344	$	37,345
Cleco Power’s 50% equity	$	18,172	$	18,672
Cleco Power’s maximum exposure to loss	$	18,172	$	18,672

Equity Method Investments

The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2017		2016		2017		2016
Operating revenue	$	392	$	1,034	$	1,997	$	4,661
Operating expenses	392		1,034		1,997		4,661
Income before taxes	$	—	$	—	$	—	$	—

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

INCEPTION TO DATE (THOUSANDS)	AT SEPT. 30, 2017			AT DEC. 31, 2016
Purchase price	$	12,873		$	12,873
Cash contributions	6,399			6,399
Dividends	(1,100		)	(600		)
Total equity investment in investee	$	18,172		$	18,672

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Affiliate Transactions (Tables)

9 Months Ended

Sep. 30, 2017

Cleco Power [Member]

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 SEPT. 30, 2017				AT DEC. 31, 2016
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	282	$	526	$	3	$	119
Support Group	1,262		7,767		1,402		7,071
Other (1)	1		—		1		—
Total	$	1,545	$	8,293	$	1,406	$	7,190
(1) Represents Attala and Perryville.

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Accumulated Other Comprehensive Loss (Tables)

9 Months Ended

Sep. 30, 2017

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 SEPT. 30, 2017								FOR THE NINE MONTHS ENDED SEPT. 30, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI			POSTRETIREMENT BENFIT NET GAIN (LOSS)			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	(631	)	$	—	$	(631	)	$	1,500		$	—	$	1,500
Other comprehensive loss before reclassifications
Postretirement benefit adjustments during the period	—			—		—			(2,065		)	—		(2,065		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net gain	(44		)	—		(44		)	(110		)	—		(110		)
Net current-period other comprehensive loss	(44		)	—		(44		)	(2,175		)	—		(2,175		)
Balances, Sept. 30, 2017	$	(675	)	$	—	$	(675	)	$	(675	)	$	—	$	(675	)

	FOR THE THREE MONTHS ENDED SEPT. 30, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
Balances, beginning of period	$	—		$	—	$	—
Other comprehensive loss before reclassifications
Postretirement benefits adjustment during the period	(2,308		)	—		(2,308		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	3			—		3
Net current-period other comprehensive loss	(2,305		)	—		(2,305		)
Balances, Sept. 30, 2016	$	(2,305	)	$	—	$	(2,305	)

	FOR THE NINE MONTHS ENDED SEPT. 30, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
PREDECESSOR
Balances, beginning of period	$	(20,857	)	$	(5,728	)	$	(26,585	)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	587			—			587
Reclassification of net loss to interest charges	—			60			60
Net current-period other comprehensive income	587			60			647
Balances, Apr. 12, 2016	$	(20,270	)	$	(5,668	)	$	(25,938	)
SUCCESSOR(1)
Balances, Apr. 13, 2016	$	—		$	—		$	—
Other comprehensive loss before reclassifications
Postretirement benefits adjustment during the period	(2,308		)	—			(2,308		)
Amounts reclassified from accumulated other comprehensive loss
Amortization of postretirement benefit net loss	3			—			3
Net current-period other comprehensive loss	(2,305		)	—			(2,305		)
Balances, Sept. 30, 2016	$	(2,305	)	$	—		$	(2,305	)
(1) As a result of the Merger, accumulated other comprehensive income was reduced to zero on April 13, 2016, as required by acquisition accounting.

Cleco Power [Member]

Accumulated Other Comprehensive Loss [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss)

Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30, 2017									FOR THE NINE MONTHS ENDED SEPT. 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	$	(8,132	)	$	(5,411	)	$	(13,543	)	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive loss before reclassifications
Postretirement benefit adjustments during the period	—			—			—			(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	167			—			167			524			—			524
Reclassification of net loss to interest charges	—			53			53			—			159			159
Net current-period other comprehensive income (loss)	167			53			220			(60		)	159			99
Balances, Sept. 30, 2017	$	(7,965	)	$	(5,358	)	$	(13,323	)	$	(7,965	)	$	(5,358	)	$	(13,323	)

	FOR THE THREE MONTHS ENDED SEPT. 30, 2016									FOR THE NINE MONTHS ENDED SEPT. 30, 2016
(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	$	(10,983	)	$	(5,622	)	$	(16,605	)	$	(11,364	)	$	(5,728	)	$	(17,092	)
Other comprehensive income before reclassifications:
Postretirement benefit adjustments during the period	2,013			—			2,013			2,013			—			2,013
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	167			—			167			548			—			548
Reclassification of net loss to interest charges	—			53			53			—			159			159
Net current-period other comprehensive income	2,180			53			2,233			2,561			159			2,720
Balances, Sept. 30, 2016	$	(8,803	)	$	(5,569	)	$	(14,372	)	$	(8,803	)	$	(5,569	)	$	(14,372	)

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Summary of Significant Accounting Policies, Basis of Presentation (Details) - Cleco Holdings [Member]	Apr. 13, 2016 $ / shares
Business Acquisition [Line Items]
Common stock, par value (in dollars per share)	$ 1.00
Share price at the time of the Merger (in dollars per share)	$ 55.37

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Summary of Significant Accounting Policies, Goodwill (Details) - USD ($)	Aug. 01, 2017	Sep. 30, 2017	Dec. 31, 2016	Apr. 13, 2016
Goodwill [Line Items]
Goodwill recognized in connection with the completion of the Merger		$ 1,490,797,000	$ 1,490,797,000	$ 1,490,797,000
Carrying Value of Equity		$ 2,037,674,000	$ 2,046,763,000
Operating Segments [Member] | Cleco Power [Member]
Goodwill [Line Items]
Accumulated impairment loss on goodwill	$ 0
Fair Value of Equity	3,340,000,000
Carrying Value of Equity	$ 3,250,000,000
Reporting Unit, Percentage of Fair Value in Excess of Carrying Amount	3.00%
Reporting Unit, Amount of Fair Value in Excess of Carrying Amount	$ 89,500,000
Fair Value Inputs, Weighted-average cost of capital	5.20%
Fair Value Inputs, Long-term Cash Flow Growth Rate	2.50%
Operating Segments [Member] | Cleco Power [Member] | WACC, Lower Alternate [Member]
Goodwill [Line Items]
Fair Value of Equity	$ 3,430,000,000
Fair Value Inputs, Weighted-average cost of capital	5.10%
Operating Segments [Member] | Cleco Power [Member] | WACC, Higher Alternate [Member]
Goodwill [Line Items]
Fair Value of Equity	$ 3,250,000,000
Fair Value Inputs, Weighted-average cost of capital	5.30%
Operating Segments [Member] | Cleco Power [Member] | Long-term Cash Flow Growth Rate, Lower Alternate [Member]
Goodwill [Line Items]
Fair Value of Equity	$ 3,250,000,000
Fair Value Inputs, Long-term Cash Flow Growth Rate	2.40%
Operating Segments [Member] | Cleco Power [Member] | Long-term Cash Flow Growth Rate, Higher Alternate [Member]
Goodwill [Line Items]
Fair Value of Equity	$ 3,430,000,000
Fair Value Inputs, Long-term Cash Flow Growth Rate	2.60%

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Summary of Significant Accounting Policies, Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	9 Months Ended		18 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Dec. 31, 2016	Apr. 01, 2016
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	$ 8,874		$ 8,874	$ 23,084
Total non-current	24,547		24,547	23,410
Total restricted cash and cash equivalents	33,421		33,421	46,494
Cleco Katrina Rita Storm Recovery Bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	3,798		3,798	9,213
Cleco Power's charitable contributions [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	1,200		1,200	1,200
Total non-current	3,640		3,640	4,179
Cleco Power's rate credit escrow [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	3,876		3,876	12,671
Total non-current	2,887		2,887	1,831
Diversified Lands’ mitigation escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Total non-current	21		21	21
Cleco Power’s future storm restoration costs
Restricted Cash and Cash Equivalents Items [Line Items]
Total non-current	17,999		17,999	17,379
Katrina Rita storm recovery collections, net of administration fees
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (Decrease) in Restricted Cash	16,100
Katrina Rita Bond Principal Payments
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (Decrease) in Restricted Cash	(17,900)
Katrina Rita Bond Interest Payments [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (Decrease) in Restricted Cash	(3,600)
Cleco Power [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	8,874		8,874	23,084
Total non-current	24,526		24,526	23,389
Total restricted cash and cash equivalents	33,400		33,400	46,473
Increase (Decrease) in Restricted Cash	(13,073)	$ 29,096
Cleco Power [Member] | Cleco Katrina Rita Storm Recovery Bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	3,798		3,798	9,213
Cleco Power [Member] | Cleco Power's charitable contributions [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	1,200		1,200	1,200
Total non-current	3,640		3,640	4,179
Total restricted cash and cash equivalents					$ 6,000
Increase (Decrease) in Restricted Cash			(1,200)
Cleco Power [Member] | Cleco Power's rate credit escrow [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	3,876		3,876	12,671
Total non-current	2,887		2,887	1,831
Total restricted cash and cash equivalents					$ 136,000
Increase (Decrease) in Restricted Cash			(129,400)
Cleco Power [Member] | Cleco Power’s future storm restoration costs
Restricted Cash and Cash Equivalents Items [Line Items]
Total non-current	$ 17,999		$ 17,999	$ 17,379

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Summary of Significant Accounting Policies, Risk Management (Details) $ in Millions	Sep. 30, 2017 USD ($) contract MMBTU	Dec. 31, 2016 USD ($) MMBTU	Sep. 30, 2016 contract	Apr. 12, 2016 contract
Successor | Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk	0		0
Predecessor | Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk				0
Cleco Power [Member] | Other Current Assets [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
FTRs in Energy risk management asset | $	$ 13.4	$ 7.9
Cleco Power [Member] | Other Current Liabilities [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
FTRs in Energy risk management liability | $	$ 0.5	$ 0.2
Cleco Power [Member] | Open Natural Gas Positions
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk | MMBTU	0	0
Cleco Power [Member] | Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk	0		0

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Summary of Significant Accounting Policies, Stock-Based Compensation (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended	9 Months Ended
	Apr. 30, 2016	Apr. 12, 2016	Sep. 30, 2017
Predecessor
Stock-Based Compensation [Line Items]
Tax benefit from pretax compensation expense on non-vested stock		$ 1.2
Predecessor | Non-vested Stock [Member]
Stock-Based Compensation [Line Items]
Non-vested stock granted during the period pursuant to the LTIP (in shares)		0
Pretax compensation expense on non-vested stock		$ 3.2
Merger expense due to accelerated vesting of the LTIP shares	$ 2.3
Cleco Power [Member]
Stock-Based Compensation [Line Items]
Tax benefit from pretax compensation expense on non-vested stock			$ 0.4
Cleco Power [Member] | Non-vested Stock [Member]
Stock-Based Compensation [Line Items]
Pretax compensation expense on non-vested stock			$ 1.0

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Business Combination (Details) - USD ($)		9 Months Ended
	Apr. 13, 2016	Sep. 30, 2017	Dec. 31, 2016	Apr. 07, 2016
Business Acquisition [Line Items]
Accumulated depreciation on the date of the Merger	$ 0	$ 162,040,000	$ 75,816,000
Deferred tax liabilities recognized for goodwill	0
Adjustments to fair value of assets acquired as a result of the Merger		0
Adjustments to fair value of liabilities acquired as a result of the Merger		0
Purchase Price Allocation [Abstract]
Current assets	455,016,000
Property, plant, and equipment, net	3,432,144,000
Goodwill	1,490,797,000	$ 1,490,797,000	1,490,797,000
Other long-term assets	1,023,487,000
Current liabilities	228,515,000
Net deferred income tax liabilities	1,059,939,000
Other deferred credits	279,379,000
Long-term debt, net	1,470,126,000
Total purchase price	3,363,485,000
Property, Plant, and Equipment [Member]
Fair Value Adjustments [Abstract]
Assets	(1,334,932,000)
Accumulated Depreciation [Member]
Fair Value Adjustments [Abstract]
Assets	(1,565,776,000)
Goodwill [Member]
Fair Value Adjustments [Abstract]
Assets	1,490,797,000
Intangible Assets [Member]
Fair Value Adjustments [Abstract]
Assets	91,826,000
Regulatory Asset [Member]
Fair Value Adjustments [Abstract]
Assets	250,409,000
Deferred Income Tax Liabilities [Member]
Fair Value Adjustments [Abstract]
Liabilities	126,853,000
Other Deferred Credits [Member]
Fair Value Adjustments [Abstract]
Liabilities	21,175,000
Long-term Debt [Member]
Fair Value Adjustments [Abstract]
Liabilities	$ 198,599,000
Cleco Trade Name [Member]
Business Acquisition [Line Items]
Trade name intangible asset, useful life (in years)		20 years
Non-vested Stock [Member]
Business Acquisition [Line Items]
Remaining LTIP equity awards as of the close of the Merger	0
Merger Commitments, rate credits | LPSC
Business Acquisition [Line Items]
Merger commitments				$ 136,000,000
Merger Commitments, economic development contribution | LPSC
Business Acquisition [Line Items]
Merger commitments				7,000,000
Merger Commitments, charitable contribution, disbursed over 5 years | LPSC
Business Acquisition [Line Items]
Merger commitments				6,000,000
Merger Commitments, economic development contribution, disbursed over 5 years | LPSC
Business Acquisition [Line Items]
Merger commitments				2,500,000
Merger Commitments, cost savings | LPSC
Business Acquisition [Line Items]
Merger commitments				1,200,000
Cleco Holdings [Member]
Business Acquisition [Line Items]
Total purchase price consideration	$ 3,360,000,000
Cleco Holdings [Member] | Cash Paid to Cleco shareholders [Member]
Business Acquisition [Line Items]
Purchase price consideration, cash paid	3,350,000,000
Cleco Holdings [Member] | Cash Paid for Cleco LTIP equity awards [Member]
Business Acquisition [Line Items]
Purchase price consideration, cash paid	$ 9,500,000
Cleco Power [Member]
Business Acquisition [Line Items]
Accumulated depreciation on the date of the Merger		$ 1,687,337,000	$ 1,618,241,000
Cleco Power [Member] | Merger Commitments, rate credits | LPSC
Business Acquisition [Line Items]
Merger commitments				136,000,000
Cleco Power [Member] | Merger Commitments, economic development contribution | LPSC
Business Acquisition [Line Items]
Merger commitments				7,000,000
Cleco Power [Member] | Merger Commitments, charitable contribution, disbursed over 5 years | LPSC
Business Acquisition [Line Items]
Merger commitments				6,000,000
Cleco Power [Member] | Merger Commitments, economic development contribution, disbursed over 5 years | LPSC
Business Acquisition [Line Items]
Merger commitments				2,500,000
Cleco Power [Member] | Merger Commitments, cost savings | LPSC
Business Acquisition [Line Items]
Merger commitments				$ 1,200,000

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Regulatory Assets and Liabilities, Summary of Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Total regulatory assets, net	$ 720,017	$ 739,683
Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	271,925	285,737
Total regulatory assets, net	533,413	543,973
Cleco Power [Member] | Regulatory assets – deferred taxes, net
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	240,431	237,449
Cleco Power [Member] | Mining costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,461	6,372
Cleco Power [Member] | Interest costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,590	4,860
Cleco Power [Member] | AROs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,590	2,096
Cleco Power [Member] | Postretirement costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	137,815	145,268
Cleco Power [Member] | Tree trimming costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	6,801	5,549
Cleco Power [Member] | Training costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	6,591	6,708
Cleco Power [Member] | Surcredits, net
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	3,084	5,876
Cleco Power [Member] | AMI deferred revenue requirement
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,363	4,772
Cleco Power [Member] | Emergency declarations
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	3,976	0
Cleco Power [Member] | Production operations and maintenance expenses
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	9,656	13,999
Cleco Power [Member] | AFUDC equity gross-up
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	70,046	70,423
Cleco Power [Member] | Acquisition/ transaction costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,362	2,442
Cleco Power [Member] | Acquisition/ transaction costs | Coughlin transaction costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	976	999
Cleco Power [Member] | Financing costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,385	8,663
Cleco Power [Member] | Biomass costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	0	18
Cleco Power [Member] | MISO integration costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	702	1,404
Cleco Power [Member] | Corporate franchise tax
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	968	1,308
Cleco Power [Member] | MATS costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	3,846	4,270
Cleco Power [Member] | Other
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	713	710
Cleco Power [Member] | Accumulated deferred fuel
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	21,057	20,787
Cleco Holdings [Member] | Postretirement costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	21,872	23,362
Cleco Holdings [Member] | Financing costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,708	8,966
Cleco Holdings [Member] | Fair value of long-term debt
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	149,256	155,776
Cleco Holdings [Member] | Debt issuance costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	$ 6,768	$ 7,606

XML

Regulatory Assets and Liabilities, Additional Disclosures (Details) - USD ($) $ in Millions		3 Months Ended
	Mar. 01, 2017	Sep. 30, 2017
Regulatory Assets [Line Items]
Derecognized fair value adjustment and debt issuance costs related to debt redemption	$ 0.7
Cleco Power [Member] | Emergency declarations
Regulatory Assets [Line Items]
Regulatory Asset, Amortization Period		3 years

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Fair Value Accounting, Carrying Value and Estimated Fair Value (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Financial instruments not marked-to-market [Abstract]
Deferred debt issuance costs not included in the carrying value of long-term debt	$ 11,200	$ 11,700
Carrying Value
Financial instruments not marked-to-market [Abstract]
Long-term debt	2,743,987	2,768,149
Fair Value
Financial instruments not marked-to-market [Abstract]
Long-term debt	2,831,805	2,754,518
Cleco Power [Member]
Financial instruments not marked-to-market [Abstract]
Deferred debt issuance costs not included in the carrying value of long-term debt	8,600	9,400
Cleco Power [Member] | Carrying Value
Financial instruments not marked-to-market [Abstract]
Long-term debt	1,244,731	1,262,373
Cleco Power [Member] | Fair Value
Financial instruments not marked-to-market [Abstract]
Long-term debt	$ 1,428,761	$ 1,418,693

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Fair Value Accounting, Fair Value Measurements and Disclosures(Details)	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017 USD ($) $ / MW	Sep. 30, 2016 USD ($)	Apr. 12, 2016 USD ($)	Sep. 30, 2016 USD ($)	Sep. 30, 2017 USD ($) $ / MW	Sep. 30, 2016 USD ($)	Dec. 31, 2016 USD ($) $ / MW
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
FTR Forward Price - per MWh, Low | $ / MW	(3.07)				(3.07)		(3.61)
FTRs Forward Price - per MWh, High | $ / MW	5.87				5.87		6.04
Fair Value, Concentration of Risk, Amount of Money Market Funds in Cash and Cash Equivalents	$ 1,800,000				$ 1,800,000		$ 20,000,000
Fair Value, Assets and Liabilities, Transfers between Levels, Amount	0				0		0
Restricted Cash and Cash Equivalents, Current
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Institutional Money Market Funds	8,900,000				8,900,000		23,100,000
Restricted Cash and Cash Equivalents, Noncurrent
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Institutional Money Market Funds	24,400,000				24,400,000		23,300,000
Measured On A Recurring Basis
Asset Description [Abstract]
Institutional money market funds	35,117,000				35,117,000		66,410,000
FTR assets	13,425,000				13,425,000		7,884,000
Total Assets	48,542,000				48,542,000		74,294,000
Liability Description [Abstract]
FTR liabilities	538,000				538,000		201,000
Total Liabilities	538,000				538,000		201,000
Price Risk Derivative
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	17,943,000	$ 13,618,000
Unrealized gains (losses)	1,591,000	1,840,000
Purchases	419,000	164,000
Settlements	(7,066,000)	(6,046,000)
Ending balance	12,887,000	9,576,000		$ 9,576,000	12,887,000	$ 9,576,000
Quoted Prices in Active Markets for Identical Assets (Level 1) | Measured On A Recurring Basis
Asset Description [Abstract]
Institutional money market funds	0				0		0
FTR assets	0				0		0
Total Assets	0				0		0
Liability Description [Abstract]
FTR liabilities	0				0		0
Total Liabilities	0				0		0
Significant Other Observable Inputs (Level 2) | Measured On A Recurring Basis
Asset Description [Abstract]
Institutional money market funds	35,117,000				35,117,000		66,410,000
FTR assets	0				0		0
Total Assets	35,117,000				35,117,000		66,410,000
Liability Description [Abstract]
FTR liabilities	0				0		0
Total Liabilities	0				0		0
Significant Unobservable Inputs (Level 3) | Measured On A Recurring Basis
Asset Description [Abstract]
Institutional money market funds	0				0		0
FTR assets	13,425,000				13,425,000		7,884,000
Total Assets	13,425,000				13,425,000		7,884,000
Liability Description [Abstract]
FTR liabilities	538,000				538,000		201,000
Total Liabilities	538,000				538,000		201,000
Successor | Price Risk Derivative
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance				3,458,000	7,683,000
Unrealized gains (losses)				2,529,000	(791,000)
Purchases				12,772,000	23,537,000
Settlements				(9,183,000)	(17,542,000)
Ending balance	12,887,000	9,576,000	$ 3,458,000	9,576,000	12,887,000	9,576,000
Predecessor | Price Risk Derivative
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance			7,398,000	3,458,000		7,398,000
Unrealized gains (losses)			(1,031,000)
Purchases			2,070,000
Settlements			(4,979,000)
Ending balance			3,458,000
Cleco Power [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Cash and Cash Equivalents	500,000				500,000		18,700,000
Cleco Power [Member] | Restricted Cash and Cash Equivalents, Current
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Institutional Money Market Funds	8,900,000				8,900,000		23,100,000
Cleco Power [Member] | Restricted Cash and Cash Equivalents, Noncurrent
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Institutional Money Market Funds	24,400,000				24,400,000		23,300,000
Cleco Power [Member] | Measured On A Recurring Basis
Asset Description [Abstract]
Institutional money market funds	33,796,000				33,796,000		65,089,000
FTR assets	13,425,000				13,425,000		7,884,000
Total Assets	47,221,000				47,221,000		72,973,000
Liability Description [Abstract]
FTR liabilities	538,000				538,000		201,000
Total Liabilities	538,000				538,000		201,000
Cleco Power [Member] | Price Risk Derivative
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	17,943,000	13,618,000	$ 7,398,000		7,683,000	7,398,000
Unrealized gains (losses)	1,591,000	1,840,000			(791,000)	1,498,000
Purchases	419,000	164,000			23,537,000	14,842,000
Settlements	(7,066,000)	(6,046,000)			(17,542,000)	(14,162,000)
Ending balance	12,887,000	$ 9,576,000		$ 9,576,000	12,887,000	$ 9,576,000
Cleco Power [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) | Measured On A Recurring Basis
Asset Description [Abstract]
Institutional money market funds	0				0		0
FTR assets	0				0		0
Total Assets	0				0		0
Liability Description [Abstract]
FTR liabilities	0				0		0
Total Liabilities	0				0		0
Cleco Power [Member] | Significant Other Observable Inputs (Level 2) | Measured On A Recurring Basis
Asset Description [Abstract]
Institutional money market funds	33,796,000				33,796,000		65,089,000
FTR assets	0				0		0
Total Assets	33,796,000				33,796,000		65,089,000
Liability Description [Abstract]
FTR liabilities	0				0		0
Total Liabilities	0				0		0
Cleco Power [Member] | Significant Unobservable Inputs (Level 3) | Measured On A Recurring Basis
Asset Description [Abstract]
Institutional money market funds	0				0		0
FTR assets	13,425,000				13,425,000		7,884,000
Total Assets	13,425,000				13,425,000		7,884,000
Liability Description [Abstract]
FTR liabilities	538,000				538,000		201,000
Total Liabilities	$ 538,000				$ 538,000		$ 201,000

XML

Fair Value Accounting, Commodity Contracts (Details) $ in Thousands, MWh in Millions	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017 USD ($) MMBTU MWh	Sep. 30, 2016 USD ($)	Apr. 12, 2016 USD ($)	Sep. 30, 2016 USD ($)	Sep. 30, 2017 USD ($) MMBTU MWh	Sep. 30, 2016 USD ($)	Dec. 31, 2016 USD ($) MMBTU MWh
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument
FTRs, at Fair Value, Net [Abstract]
Commodity-related contracts, net	$ 12,887				$ 12,887		$ 7,683
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income	6,295	$ 4,652
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Energy risk management assets
FTRs, at Fair Value, Net [Abstract]
FTRs in energy risk management assets	13,425				13,425		7,884
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Energy risk management liabilities
FTRs, at Fair Value, Net [Abstract]
FTRs in Energy risk management liabilities	538				538		$ 201
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Accumulated deferred fuel
FTRs [Abstract]
Unrealized gains (losses) associated with FTRs not recognized in income on derivatives	1,600				(800)
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Electric operations
FTRs [Abstract]
Gain on FTRs recognized in income	14,062	9,718
Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Power purchased for utility customers
FTRs [Abstract]
Loss on FTRs recognized in income	$ (7,767)	(5,066)
Predecessor | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income			$ 2,802
Predecessor | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Accumulated deferred fuel
FTRs [Abstract]
Unrealized gains (losses) associated with FTRs not recognized in income on derivatives			(1,000)
Predecessor | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Electric operations
FTRs [Abstract]
Gain on FTRs recognized in income			8,563
Predecessor | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Power purchased for utility customers
FTRs [Abstract]
Loss on FTRs recognized in income			$ (5,761)
Successor | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income				$ 11,725	16,413
Successor | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Accumulated deferred fuel
FTRs [Abstract]
Unrealized gains (losses) associated with FTRs not recognized in income on derivatives		1,800		2,500
Successor | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Electric operations
FTRs [Abstract]
Gain on FTRs recognized in income				23,467	35,172
Successor | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Power purchased for utility customers
FTRs [Abstract]
Loss on FTRs recognized in income				$ (11,742)	$ (18,759)
Cleco Power [Member]
FTRs [Abstract]
Volume of FTRs Held (MWh) | MWh	14.4				14.4		9.0
Cleco Power [Member] | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument
FTRs, at Fair Value, Net [Abstract]
Commodity-related contracts, net	$ 12,887				$ 12,887		$ 7,683
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income	6,295	4,652			16,413	$ 14,527
Cleco Power [Member] | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Energy risk management assets
FTRs, at Fair Value, Net [Abstract]
FTRs in energy risk management assets	13,425				13,425		7,884
Cleco Power [Member] | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Energy risk management liabilities
FTRs, at Fair Value, Net [Abstract]
FTRs in Energy risk management liabilities	538				538		$ 201
Cleco Power [Member] | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Accumulated deferred fuel
FTRs [Abstract]
Unrealized gains (losses) associated with FTRs not recognized in income on derivatives	1,600	1,800			(800)	1,500
Cleco Power [Member] | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Electric operations
FTRs [Abstract]
Gain on FTRs recognized in income	14,062	9,718			35,172	32,030
Cleco Power [Member] | Price Risk Derivative | Derivatives Not Designated As Hedging Instrument | Power purchased for utility customers
FTRs [Abstract]
Loss on FTRs recognized in income	$ (7,767)	$ (5,066)			$ (18,759)	$ (17,503)
Cleco Power [Member] | Open Natural Gas Positions
FTRs [Abstract]
Number of open natural gas positions | MMBTU	0				0		0

XML

Debt, Long-term Debt (Details) - USD ($) $ in Millions	Apr. 28, 2017	Mar. 01, 2017	May 31, 2016	Mar. 31, 2008
Cleco Katrina Rita's storm recovery bonds, 5.61, due 2023 [Member]
Debt Instrument [Line Items]
Debt amount				$ 180.6
Cleco Katrina Rita's storm recovery bonds, 5.61, due 2023 [Member]
Debt Instrument [Line Items]
Debt amount				$ 113.0
Interest rate, stated percentage (in hundredths)				4.41%
Repayment of Senior Notes through cash		$ 1.1
Interest Expense, Debt		$ 0.1
Cleco Holdings [Member] | Cleco Holdings' senior notes, 4.973%, due 2046 [Member]
Debt Instrument [Line Items]
Debt amount			$ 350.0
Interest rate, stated percentage (in hundredths)			4.973%
Interest rate on original debt (in hundredths)	4.973%
Interest rate on converted debt (in hundredths)	4.973%
Cleco Holdings [Member] | Cleco Corporate Holdings, Acquisition Loan Facility [Member]
Debt Instrument [Line Items]
Debt amount			$ 1,350.0
Cleco Holdings [Member] | Cleco Holdings' senior notes, 3.743%, due 2026 [Member]
Debt Instrument [Line Items]
Debt amount			$ 535.0
Interest rate, stated percentage (in hundredths)			3.743%
Interest rate on original debt (in hundredths)	3.743%
Interest rate on converted debt (in hundredths)	3.743%

XML

Debt Short-term Debt (Details) - Cleco Power [Member] - Line of Credit [Member] - USD ($) $ in Millions	Sep. 30, 2017	Dec. 31, 2016
Short-term Debt [Line Items]
Short-term Debt	$ 6.5	$ 0.0
Short-term Debt, Percentage Bearing Variable Interest Rate	2.98%
Maximum
Short-term Debt [Line Items]
Short-term Debt	$ 10.0

XML

Pension Plan and Employee Benefits, Pension Plan and Other Benefits Plan (Details) - USD ($)	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Pension Plan [Member]
Components of periodic benefit costs [Abstract]
Service cost	$ 2,260,000	$ 2,229,000
Interest cost	5,412,000	5,455,000
Expected return on plan assets	(6,016,000)	(6,001,000)
Prior period service (credit) cost	(18,000)	(18,000)
Net loss (gain)	2,502,000	3,365,000
Total benefit cost	4,140,000	5,030,000
Pension Plan [Member] | Other Subsidiaries [Member]
Components of periodic benefit costs [Abstract]
Total benefit cost	500,000	400,000
Pension Plan [Member] | Successor
Components of periodic benefit costs [Abstract]
Service cost				$ 4,122,000	$ 6,779,000
Interest cost				10,124,000	16,235,000
Expected return on plan assets				(11,195,000)	(18,048,000)
Prior period service (credit) cost				(33,000)	(53,000)
Net loss (gain)				5,211,000	7,506,000
Total benefit cost				8,229,000	12,419,000
Pension Plan [Member] | Successor | Other Subsidiaries [Member]
Components of periodic benefit costs [Abstract]
Total benefit cost				800,000	1,400,000
Pension Plan [Member] | Predecessor
Components of periodic benefit costs [Abstract]
Service cost			$ 2,563,000
Interest cost			6,242,000
Expected return on plan assets			(6,812,000)
Prior period service (credit) cost			(20,000)
Net loss (gain)			2,798,000
Total benefit cost			4,771,000
Pension Plan [Member] | Predecessor | Other Subsidiaries [Member]
Components of periodic benefit costs [Abstract]
Total benefit cost			500,000
Other Postretirement Benefits Plan [Member]
Components of periodic benefit costs [Abstract]
Service cost	314,000	380,000
Interest cost	372,000	420,000
Expected return on plan assets	0	0
Prior period service (credit) cost	0	0
Net loss (gain)	(32,000)	0
Total benefit cost	654,000	800,000
Assets Held-in-trust, Noncurrent	0				0
Current portion of other benefits liability	3,854,000				3,854,000		$ 3,854,000
Noncurrent portion of other benefits liability	39,296,000				39,296,000		40,196,000
Other Postretirement Benefits Plan [Member] | Successor
Components of periodic benefit costs [Abstract]
Service cost				709,000	1,084,000
Interest cost				784,000	1,176,000
Expected return on plan assets				0	0
Prior period service (credit) cost				0	0
Net loss (gain)				0	(37,000)
Total benefit cost				$ 1,493,000	2,223,000
Other Postretirement Benefits Plan [Member] | Predecessor
Components of periodic benefit costs [Abstract]
Service cost			431,000
Interest cost			476,000
Expected return on plan assets			0
Prior period service (credit) cost			34,000
Net loss (gain)			181,000
Total benefit cost			$ 1,122,000
Cleco Power [Member] | Other Postretirement Benefits Plan [Member]
Components of periodic benefit costs [Abstract]
Total benefit cost	800,000	$ 800,000			2,500,000	$ 2,500,000
Current portion of other benefits liability	3,345,000				3,345,000		3,345,000
Noncurrent portion of other benefits liability	$ 34,147,000				$ 34,147,000		$ 34,892,000

XML

Pension Plan and Employee Benefits, SERP (Details) - SERP Benefits [Member] - USD ($) $ in Thousands		3 Months Ended			6 Months Ended	9 Months Ended
	Mar. 30, 2017	Sep. 30, 2017	Sep. 30, 2016	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Mar. 29, 2017	Dec. 31, 2016	Aug. 31, 2016	Apr. 13, 2016
Components of periodic benefit costs [Abstract]
Service cost		$ 123	$ 213
Interest cost		810	839
Prior period service (credit) cost		57	9
Net loss (gain)		536	511
Curtailment charge				$ 3,600
Special/contractual termination benefits	$ 300
Total benefit cost		1,412	1,554
Defined Benefit Plan, Benefit Obligation, (Increase) Decrease for Settlement				$ 3,200
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate (in hundredths)	4.08%			4.60%				4.22%		3.47%	4.15%
Current portion of SERP liability		4,431				$ 4,431			$ 4,308
Noncurrent portion of SERP liability		76,870				76,870			73,738
Successor
Components of periodic benefit costs [Abstract]
Service cost					$ 277	370
Interest cost					1,543	2,430
Prior period service (credit) cost					42	124
Net loss (gain)					1,120	1,560
Net periodic benefit cost					2,898	4,236
Curtailment charge					0	0
Special/contractual termination benefits					0	315
Total benefit cost					$ 2,898	4,551
Predecessor
Components of periodic benefit costs [Abstract]
Service cost				$ 702
Interest cost				900
Prior period service (credit) cost				(17)
Net loss (gain)				574
Net periodic benefit cost				2,193
Curtailment charge				3,602
Special/contractual termination benefits				3,222
Total benefit cost				$ 9,017
Cleco Power [Member]
Components of periodic benefit costs [Abstract]
Total benefit cost		300	$ 300			900	$ 1,100
Current portion of SERP liability		939				939			885
Noncurrent portion of SERP liability		$ 15,999				$ 15,999			$ 15,145

XML

Pension Plan and Employee Benefits, 401 (K) Plans (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense	$ 1,386	$ 1,331
Other Subsidiaries [Member]
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense	$ 234	$ 204
Successor
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense				$ 2,440	$ 4,259
Successor | Other Subsidiaries [Member]
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense				$ 378	$ 710
Predecessor
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense			$ 1,593
Predecessor | Other Subsidiaries [Member]
Defined Contribution Plan Disclosure [Line Items]
401(k) Plan expense			$ 319

XML

Income Taxes, Effective Tax Rate Reconciliation (Details)	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Effective Income Tax Rate [Line Items]
Effective tax rate	33.70%	37.40%
Successor
Effective Income Tax Rate [Line Items]
Effective tax rate				40.30%	35.50%
Predecessor
Effective Income Tax Rate [Line Items]
Effective tax rate			(704.90%)
Cleco Power [Member]
Effective Income Tax Rate [Line Items]
Effective tax rate	35.40%	35.90%			36.80%	19.50%

XML

Income Taxes, Uncertain Tax Positions (Details) - USD ($)	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
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
Cleco Power [Member]
Uncertain Tax Positions [Line Items]
Interest payable related to uncertain tax positions	0		$ 0
Interest expense related to uncertain tax positions	$ 0	$ 0

XML

Disclosures about Segments (Details) $ in Thousands	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017 USD ($) entity	Sep. 30, 2016 USD ($)	Apr. 12, 2016 USD ($)	Sep. 30, 2016 USD ($)	Sep. 30, 2017 USD ($) entity	Dec. 31, 2016 USD ($)	Apr. 13, 2016 USD ($)
Segment Reporting Information [Line Items]
Number of transmission interconnection facility subsidiaries | entity	2				2
Revenue [Abstract]
Electric operations	$ 317,589	$ 323,707
Other operations	21,282	18,976
Electric customer credits	(372)	177
Affiliate revenue	0	0
Operating revenue, net	338,499	342,860
Depreciation and amortization	42,228	42,535
Merger transaction and commitment costs	185	1,869
Interest charges	30,462	31,858
Interest income	354	318
Federal and state income tax (benefit) expense	23,054	23,700
Net (loss) income	45,304	39,621			$ 77,041
Equity investment in investees	18,172				18,172	$ 18,672
Goodwill	1,490,797				1,490,797	1,490,797	$ 1,490,797
Total Segment Assets	6,397,701				6,397,701	6,343,144
Operating Segments [Member] | Other [Member]
Revenue [Abstract]
Electric operations	(2,420)	(2,574)
Other operations	514	517
Electric customer credits	0	0
Affiliate revenue	13,517	13,060
Operating revenue, net	11,611	11,003
Depreciation and amortization	2,179	2,182
Merger transaction and commitment costs	185	1,869
Interest charges	13,331	12,709
Interest income	31	82
Federal and state income tax (benefit) expense	(7,038)	(5,728)
Net (loss) income	(9,548)	(12,952)
Operating Segments [Member] | Cleco Power [Member]
Revenue [Abstract]
Electric operations	320,009	326,281
Other operations	20,768	18,460
Electric customer credits	(372)	177
Affiliate revenue	209	213
Operating revenue, net	340,614	345,131
Depreciation and amortization	40,049	40,353
Merger transaction and commitment costs	0	0
Interest charges	17,141	19,177
Interest income	332	264
Federal and state income tax (benefit) expense	30,092	29,427
Net (loss) income	54,852	52,572
Intersegment Elimination [Member]
Revenue [Abstract]
Electric operations	0	0
Other operations	0	(1)
Electric customer credits	0	0
Affiliate revenue	(13,726)	(13,273)
Operating revenue, net	(13,726)	(13,274)
Depreciation and amortization	0	0
Merger transaction and commitment costs	0	0
Interest charges	(10)	(28)
Interest income	(9)	(28)
Federal and state income tax (benefit) expense	0	1
Net (loss) income	0	$ 1
Successor
Revenue [Abstract]
Electric operations				$ 553,634	839,080
Other operations				33,110	59,627
Electric customer credits				(381)	(1,045)
Affiliate revenue				0	0
Operating revenue, net				586,363	897,662
Depreciation and amortization				76,695	124,630
Merger transaction and commitment costs				173,172	187
Interest charges				58,323	92,800
Interest income				515	1,046
Federal and state income tax (benefit) expense				(28,502)	42,381
Net (loss) income				(42,294)	77,041
Additions to property, plant, and equipment				102,677	185,609
Equity investment in investees	18,172				18,172	18,672
Goodwill						1,490,797
Total Segment Assets	6,397,701				6,397,701	6,343,144
Successor | Operating Segments [Member] | Other [Member]
Revenue [Abstract]
Electric operations				(4,805)	(8,337)
Other operations				965	1,544
Electric customer credits				0	0
Affiliate revenue				23,823	41,882
Operating revenue, net				19,983	35,089
Depreciation and amortization				5,198	6,351
Merger transaction and commitment costs				21,671	187
Interest charges				22,430	40,297
Interest income				177	271
Federal and state income tax (benefit) expense				(18,474)	(20,629)
Net (loss) income				(32,968)	(31,398)
Additions to property, plant, and equipment				393	2,005
Equity investment in investees	0				0	0
Goodwill	0				0	0
Total Segment Assets	592,681				592,681	614,959
Successor | Operating Segments [Member] | Cleco Power [Member]
Revenue [Abstract]
Electric operations				558,439	847,417
Other operations				32,145	58,083
Electric customer credits				(381)	(1,045)
Affiliate revenue				406	649
Operating revenue, net				590,609	905,104
Depreciation and amortization				71,498	118,280
Merger transaction and commitment costs				151,501	0
Interest charges				35,937	52,654
Interest income				382	926
Federal and state income tax (benefit) expense				(10,028)	63,010
Net (loss) income				(9,326)	108,439
Additions to property, plant, and equipment				102,284	183,604
Equity investment in investees	18,172				18,172	18,672
Goodwill	1,490,797				1,490,797	1,490,797
Total Segment Assets	5,822,302				5,822,302	5,758,245
Successor | Intersegment Elimination [Member]
Revenue [Abstract]
Electric operations				0	0
Other operations				0	0
Electric customer credits				0	0
Affiliate revenue				(24,229)	(42,531)
Operating revenue, net				(24,229)	(42,531)
Depreciation and amortization				(1)	(1)
Merger transaction and commitment costs				0	0
Interest charges				(44)	(151)
Interest income				(44)	(151)
Federal and state income tax (benefit) expense				0	0
Net (loss) income				0	0
Additions to property, plant, and equipment				$ 0	0
Equity investment in investees	0				0	0
Goodwill	0				0	0
Total Segment Assets	$ (17,282)				$ (17,282)	$ (30,060)
Predecessor
Revenue [Abstract]
Electric operations			$ 281,154
Other operations			19,080
Electric customer credits			(364)
Affiliate revenue			0
Operating revenue, net			299,870
Depreciation and amortization			44,076
Merger transaction and commitment costs			34,912
Interest charges			22,123
Interest income			265
Federal and state income tax (benefit) expense			3,468
Net (loss) income			(3,960)
Additions to property, plant, and equipment			42,392
Predecessor | Operating Segments [Member] | Other [Member]
Revenue [Abstract]
Electric operations			0
Other operations			587
Electric customer credits			0
Affiliate revenue			15,024
Operating revenue, net			15,611
Depreciation and amortization			377
Merger transaction and commitment costs			34,928
Interest charges			295
Interest income			69
Federal and state income tax (benefit) expense			(9,525)
Net (loss) income			(25,508)
Additions to property, plant, and equipment			39
Predecessor | Operating Segments [Member] | Cleco Power [Member]
Revenue [Abstract]
Electric operations			281,154
Other operations			18,493
Electric customer credits			(364)
Affiliate revenue			263
Operating revenue, net			299,546
Depreciation and amortization			43,698
Merger transaction and commitment costs			0
Interest charges			21,840
Interest income			208
Federal and state income tax (benefit) expense			12,993
Net (loss) income			21,548
Additions to property, plant, and equipment			42,353
Predecessor | Intersegment Elimination [Member]
Revenue [Abstract]
Electric operations			0
Other operations			0
Electric customer credits			0
Affiliate revenue			(15,287)
Operating revenue, net			(15,287)
Depreciation and amortization			1
Merger transaction and commitment costs			(16)
Interest charges			(12)
Interest income			(12)
Federal and state income tax (benefit) expense			0
Net (loss) income			0
Additions to property, plant, and equipment			$ 0

XML

Regulation and Rates (Details) - USD ($)		1 Months Ended				15 Months Ended	39 Months Ended
	Feb. 13, 2017	Sep. 30, 2017	Sep. 30, 2016	Jun. 30, 2016	Nov. 30, 2013	Sep. 30, 2017	Sep. 30, 2017	Oct. 31, 2017	Jun. 28, 2017	Dec. 31, 2016	Oct. 31, 2016	Apr. 07, 2016
Regulation and Rates [Line Items]
Refund due to customers		$ 3,734,000				$ 3,734,000	$ 3,734,000			$ 3,974,000
LPSC | Merger Commitments, rate credits
Regulation and Rates [Line Items]
Merger commitments												$ 136,000,000
LPSC | Merger Commitments, economic development contribution
Regulation and Rates [Line Items]
Merger commitments												7,000,000
LPSC | Merger Commitments, economic development contribution, disbursed over 5 years
Regulation and Rates [Line Items]
Merger commitments												2,500,000
LPSC | Merger Commitments, charitable contribution, disbursed over 5 years
Regulation and Rates [Line Items]
Merger commitments												6,000,000
LPSC | Merger Commitments, cost savings
Regulation and Rates [Line Items]
Merger commitments												1,200,000
Cleco Power [Member]
Regulation and Rates [Line Items]
Refund due to customers		3,734,000				3,734,000	3,734,000			3,974,000
Payments received for capital expenditures subject to refund		2,200,000				2,200,000	2,200,000
Cleco Power [Member] | LPSC | Merger Commitments, rate credits
Regulation and Rates [Line Items]
Merger commitments												136,000,000
Merger Commitment, Rate Credits issued to customers						130,000,000
Cleco Power [Member] | LPSC | Merger Commitments, economic development contribution
Regulation and Rates [Line Items]
Merger commitments												7,000,000
Merger Commitment, One-time contribution paid to the LED										$ 7,000,000
Cleco Power [Member] | LPSC | Merger Commitments, economic development contribution, disbursed over 5 years
Regulation and Rates [Line Items]
Merger commitments												2,500,000
Cleco Power [Member] | LPSC | Merger Commitments, charitable contribution, disbursed over 5 years
Regulation and Rates [Line Items]
Merger commitments												6,000,000
Cleco Power [Member] | LPSC | Merger Commitments, cost savings
Regulation and Rates [Line Items]
Customer Refundable Fees, Refund Payments		300,000
Refund due to customers		1,500,000				1,500,000	1,500,000
Merger commitments												$ 1,200,000
Cleco Power [Member] | MISO Transmission Rates | FERC
Regulation and Rates [Line Items]
Target ROE allowed by FRP (in hundredths)			10.32%		12.38%
Public Utilities, Proposed Return on Equity, Percentage (in hundredths)				9.70%	6.68%
Customer Refundable Fees, Refund Payments	$ 1,200,000
Refund due to customers		2,000,000				2,000,000	$ 2,000,000
Cleco Power [Member] | FRP | LPSC
Regulation and Rates [Line Items]
Percentage of retail earnings exceeding range to be returned to customers (in hundredths)							100.00%
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 [Member] | FRP | LPSC | Maximum
Regulation and Rates [Line Items]
Target ROE allowed by FRP (in hundredths)							10.90%
Cleco Power [Member] | FRP Monitoring report for the 12-month period ended June 30, 2016 | LPSC
Regulation and Rates [Line Items]
Refund due to customers									$ 0		$ 0
Cleco Power [Member] | Merger Commitment Monitoring report for the 12-month period ended June 30, 2016 | LPSC
Regulation and Rates [Line Items]
Refund due to customers											$ 300,000
Cleco Power [Member] | SSR [Member] | FERC
Regulation and Rates [Line Items]
Amount collected in SSR payments from MISO		$ 20,300,000				$ 20,300,000	$ 20,300,000
Subsequent Event [Member] | Cleco Power [Member] | 2017 FRP Monitoring report [Member] | LPSC
Regulation and Rates [Line Items]
Refund due to customers								$ 0
Subsequent Event [Member] | Cleco Power [Member] | 2017 Merger Commitment Monitoring report [Member] | LPSC
Regulation and Rates [Line Items]
Refund due to customers								$ 1,200,000

XML

Variable Interest Entities (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended		9 Months Ended
	Jun. 30, 2017	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Variable Interest Entity [Line Items]
Equity investment in investees		$ 18,172		$ 18,172		$ 18,672
Components of Equity Method Investments [Abstract]
Total equity investment in investee		18,172		18,172		18,672
Cleco Power [Member]
Variable Interest Entity [Line Items]
Equity investment in investees		18,172		18,172		18,672
Return of equity investment	$ 500
Components of Equity Method Investments [Abstract]
Purchase price		12,873		12,873		12,873
Cash contributions		6,399		6,399		6,399
Dividend received		(1,100)		(1,100)		(600)
Total equity investment in investee		18,172		18,172		18,672
Comparison of Carrying Amount of Assets and Liabilities to Maximum Loss Exposure [Abstract]
Oxbow's net assets/liabilities		36,344		36,344		37,345
Equity Method Investment, Summarized Financial Information [Abstract]
Operating revenue		392	$ 1,034	1,997	$ 4,661
Operating expenses		392	1,034	1,997	4,661
Income before taxes		0	$ 0	$ 0	$ 0
Cleco Power [Member] | 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		18,672
Cleco Power’s maximum exposure to loss		$ 18,172		$ 18,172		$ 18,672

XML

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Litigation (Details)		1 Months Ended					24 Months Ended	62 Months Ended
	Feb. 13, 2017 USD ($)	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2015 USD ($)	Nov. 30, 2014	Nov. 30, 2013	Dec. 31, 2015 USD ($)	Dec. 31, 2015 USD ($)	Sep. 30, 2017 USD ($)	Jan. 19, 2017 USD ($)	Dec. 31, 2016 USD ($)	Jun. 24, 2016 petition
Litigation [Abstract]
Provision for rate refund									$ 3,734,000		$ 3,974,000
Loss Contingency, Estimate of Possible Loss									4,600,000
FERC | MISO Transmission Rates
Litigation [Abstract]
Public Utilities, Requested rate increase (decrease), Percentage (in hundredths)					0.50%
Gulf Coast Spinning start up costs
Litigation [Abstract]
Allegations by plaintiff, failure to perform				$ 6,500,000
Gulf Coast Spinning construction of cotton spinning facility
Litigation [Abstract]
Allegations by plaintiff, failure to perform				$ 60,000,000
Cleco Power [Member]
Litigation [Abstract]
Provision for rate refund									3,734,000		3,974,000
Cleco Power [Member] | LPSC 2014-2015 Fuel Audit
Litigation [Abstract]
Fuel Costs							$ 582,600,000
Cost disallowance in audit, excluding interest										$ 0
Cleco Power [Member] | LPSC Nov2010-Dec2015 EAC audit
Litigation [Abstract]
Environmental expenses included in audit								$ 81,200,000
Number of petitions filed with the U.S. Court of Appeals | petition												6
Cleco Power [Member] | FERC | MISO Transmission Rates
Litigation [Abstract]
Public Utilities, Approved Return on Equity, Percentage (In hundredths)		10.32%				12.38%
Public Utilities, Proposed Return on Equity, Percentage (in hundredths)			9.70%			6.68%
Customer Refundable Fees, Refund Payments	$ 1,200,000
Provision for rate refund									$ 2,000,000
Cleco Power [Member] | Maximum | LPSC Nov2010-Dec2015 EAC audit
Litigation [Abstract]
Cost disallowance in audit, excluding interest											$ 100,000

XML

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Off-Balance Sheet Commitments and Guarantees (Details) $ in Millions	Sep. 30, 2017 USD ($)
Performance Guarantee
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 42.4
Indemnification Agreement
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	40.0
Indemnification Agreement including fundamental organizational structure
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	400.0
Cleco Power [Member] | Indemnification Agreement
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	40.0
Cleco Power [Member] | Indemnification Agreement including fundamental organizational structure
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	400.0
Cleco Power [Member] | Financial Guarantee
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 106.5

XML

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Other Commitments (Details) $ in Millions	3 Months Ended	9 Months Ended
	Sep. 30, 2017 USD ($)	Sep. 30, 2017 USD ($)	Aug. 31, 2017 Towboat	Dec. 31, 2016 USD ($)	Dec. 28, 2012 Towboat	Dec. 31, 2008
Other Commitments [Line Items]
Liability component contained in the net asset				$ 0.6
Tax Benefits in Excess of Capital Contributions	$ 11.8	$ 11.8
Period of recognition of gross investment amortization expense (in years)		10 years
Cleco Power [Member]
Other Commitments [Line Items]
Operating Lease, Expense	$ 0.3	$ 0.3
Maritime Equipment [Member] | Cleco Power [Member]
Other Commitments [Line Items]
Capital Leased Assets, Number of Units | Towboat					42
Operating Lease, Right-of-Use Asset | Towboat			42
Cleco Holdings [Member]
Other Commitments [Line Items]
Membership interest in U.S Bank New Markets Tax Credit Fund (in hundredths)						99.90%
Equity contributions to be made to the Fund		285.5
Net tax benefits and cash to be received from the Fund		303.8
Difference between equity contributions and total benefits received		$ 18.3

XML

Affiliate Transactions (Details) - Cleco Power [Member] - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Accounts receivable - affiliate	$ 1,545	$ 1,406
Accounts payable - affiliate	8,293	7,190
Cleco Holdings [Member]
Related Party Transaction [Line Items]
Accounts receivable - affiliate	282	3
Accounts payable - affiliate	526	119
Support Group [Member]
Related Party Transaction [Line Items]
Accounts receivable - affiliate	1,262	1,402
Accounts payable - affiliate	7,767	7,071
Subsidiary of Common Parent [Member]
Related Party Transaction [Line Items]
Accounts receivable - affiliate	1	1
Accounts payable - affiliate	$ 0	$ 0

XML

Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended			6 Months Ended	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Apr. 12, 2016	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Apr. 13, 2016
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period					$ 2,046,763
Net current-period other comprehensive income [Abstract]
Total other comprehensive (loss) income, net of tax	$ (44)	$ (2,305)			(2,175)
Balances, end of period	2,037,674				2,037,674
Balances	2,037,674				2,046,763
Total AOCI [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(631)	0			1,500
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period	0	(2,308)			(2,065)
Amounts reclassified from accumulated other comprehensive income, net of tax	(44)	3			(110)
Total other comprehensive (loss) income, net of tax	(44)	(2,305)			(2,175)
Balances, end of period	(675)	(2,305)		$ (2,305)	(675)	$ (2,305)
Balances	(631)	0		(2,305)	1,500	(2,305)
Postretirement Benefit Net Loss [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(631)	0			1,500
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period	0	(2,308)			(2,065)
Amounts reclassified from accumulated other comprehensive income, net of tax	(44)	3			(110)
Total other comprehensive (loss) income, net of tax	(44)	(2,305)			(2,175)
Balances, end of period	(675)	(2,305)		(2,305)	(675)	(2,305)
Balances	(631)	0		(2,305)	1,500	(2,305)
Net Loss on Cash Flow Hedges [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	0	0			0
Net current-period other comprehensive income [Abstract]
Total other comprehensive (loss) income, net of tax	0	0			0
Balances, end of period	0	0		0	0	0
Balances	0	0		0	0	0
Predecessor
Net current-period other comprehensive income [Abstract]
Total other comprehensive (loss) income, net of tax			$ 647
Predecessor | Total AOCI [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period			(26,585)	(25,938)		(26,585)
Net current-period other comprehensive income [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax			587
Total other comprehensive (loss) income, net of tax			647
Balances, end of period			(25,938)
Predecessor | Total AOCI [Member] | Interest Expense [Member]
Net current-period other comprehensive income [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax			60
Predecessor | Postretirement Benefit Net Loss [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period			(20,857)	(20,270)		(20,857)
Net current-period other comprehensive income [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax			587
Total other comprehensive (loss) income, net of tax			587
Balances, end of period			(20,270)
Predecessor | Net Loss on Cash Flow Hedges [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period			(5,728)	(5,668)		(5,728)
Net current-period other comprehensive income [Abstract]
Total other comprehensive (loss) income, net of tax			60
Balances, end of period			(5,668)
Predecessor | Net Loss on Cash Flow Hedges [Member] | Interest Expense [Member]
Net current-period other comprehensive income [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax			60
Successor
Net current-period other comprehensive income [Abstract]
Total other comprehensive (loss) income, net of tax				(2,305)	(2,175)
Successor | Total AOCI [Member]
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period				(2,308)
Amounts reclassified from accumulated other comprehensive income, net of tax				3
Total other comprehensive (loss) income, net of tax				(2,305)
Balances, end of period		(2,305)		(2,305)		(2,305)
Balances		(2,305)		(2,305)		(2,305)	$ 0
Successor | Postretirement Benefit Net Loss [Member]
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period				(2,308)
Amounts reclassified from accumulated other comprehensive income, net of tax				3
Total other comprehensive (loss) income, net of tax				(2,305)
Balances, end of period		(2,305)		(2,305)		(2,305)
Balances		(2,305)		(2,305)		(2,305)	0
Successor | Net Loss on Cash Flow Hedges [Member]
Net current-period other comprehensive income [Abstract]
Total other comprehensive (loss) income, net of tax				0
Balances, end of period		0		0		0
Balances		0		0		0	$ 0
Cleco Power [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period					1,535,202
Net current-period other comprehensive income [Abstract]
Total other comprehensive (loss) income, net of tax	220	2,233			99	2,720
Balances, end of period	1,568,740				1,568,740
Balances	1,568,740				1,535,202
Cleco Power [Member] | Total AOCI [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(13,543)	(16,605)	(17,092)		(13,422)	(17,092)
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period	0	2,013			(584)	2,013
Amounts reclassified from accumulated other comprehensive income, net of tax	167	167			524	548
Total other comprehensive (loss) income, net of tax	220	2,233			99	2,720
Balances, end of period	(13,323)	(14,372)		(14,372)	(13,323)	(14,372)
Balances	(13,543)	(16,605)	(17,092)	(14,372)	(13,422)	(17,092)
Cleco Power [Member] | Total AOCI [Member] | Interest Expense [Member]
Net current-period other comprehensive income [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax	53	53			159	159
Cleco Power [Member] | Postretirement Benefit Net Loss [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(8,132)	(10,983)	(11,364)		(7,905)	(11,364)
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period	0	2,013			(584)	2,013
Amounts reclassified from accumulated other comprehensive income, net of tax	167	167			524	548
Total other comprehensive (loss) income, net of tax	167	2,180			(60)	2,561
Balances, end of period	(7,965)	(8,803)		(8,803)	(7,965)	(8,803)
Balances	(8,132)	(10,983)	(11,364)	(8,803)	(7,905)	(11,364)
Cleco Power [Member] | Net Loss on Cash Flow Hedges [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances, beginning of period	(5,411)	(5,622)	(5,728)		(5,517)	(5,728)
Net current-period other comprehensive income [Abstract]
Total other comprehensive (loss) income, net of tax	53	53			159	159
Balances, end of period	(5,358)	(5,569)		(5,569)	(5,358)	(5,569)
Balances	(5,411)	(5,622)	$ (5,728)	$ (5,569)	(5,517)	(5,728)
Cleco Power [Member] | Net Loss on Cash Flow Hedges [Member] | Interest Expense [Member]
Net current-period other comprehensive income [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax	$ 53	$ 53			$ 159	$ 159