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 March 31, 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 May 11, 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 1ST 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)	14
	Notes to the Unaudited Condensed Consolidated Financial Statements	21
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	38
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	49
ITEM 4.	Controls and Procedures	50
PART II	Other Information
ITEM 1.	Legal Proceedings	51
ITEM 1A.	Risk Factors	51
ITEM 4.	Mine Safety Disclosures	51
ITEM 5.	Other Information	51
ITEM 6.	Exhibits	52
	Signatures	53

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CLECO POWER	2017 1ST 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
CO2	Carbon dioxide
Coughlin	Cleco Power’s 775-MW, combined-cycle power plant located in St. Landry, Louisiana
CPP	Clean Power Plan
DHLC	Dolet Hills Lignite Company, LLC, a wholly owned subsidiary of SWEPCO
Diversified Lands	Diversified Lands LLC, a wholly owned subsidiary of Cleco Holdings
Dodd-Frank Act	Dodd-Frank Wall Street Reform and Consumer Protection Act of 2010
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
EGU	Electric Generating Unit
Entergy Gulf States	Entergy Gulf States Louisiana, LLC
Entergy Louisiana	Entergy Louisiana, LLC
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.
IRP	Integrated Resource Plan
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

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CLECO
CLECO POWER	2017 1ST QUARTER FORM 10-Q

ABBREVIATION OR ACRONYM	DEFINITION
MATS	Mercury and Air Toxics Standards
Merger	Merger of Merger Sub with and into Cleco Corporation pursuant to the terms of the Merger Agreement which was completed on April 13, 2016
Merger Agreement	Agreement and Plan of Merger, dated as of October 17, 2014, by and among Cleco Partners, Merger Sub, and Cleco Corporation
Merger Commitments	Cleco Partners’, Cleco Group’s, Cleco Holdings’, and Cleco Power’s 77 commitments to the LPSC as defined in Docket No. U-33434 of which a performance report must be filed annually by October 31 for the 12 months ending June 30
Merger Sub	Cleco MergerSub Inc., previously an indirect wholly owned subsidiary of Cleco Partners that was merged with and into Cleco Corporation, with Cleco Corporation surviving the Merger, and Cleco Corporation converting to a limited liability company and changing its name to Cleco Holdings
Midstream	Cleco Midstream Resources LLC, a wholly owned subsidiary of Cleco Holdings
MIRA	Macquarie Infrastructure and Real Assets Inc.
MISO	Midcontinent Independent System Operator, Inc.
Moody’s	Moody’s Investors Service, a credit rating agency
MW	Megawatt(s)
MWh	Megawatt-hour(s)
NAAQS	National Ambient Air Quality Standards
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
NOx	Nitrogen oxides
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
Rodemacher Unit 2	A 523-MW generating unit at Cleco Power’s plant site in Boyce, Louisiana. Cleco Power has a 30% ownership interest in the capacity of Rodemacher Unit 2.
ROE	Return on Equity
RTO	Regional Transmission Organization
S&P	Standard & Poor’s Ratings Services, a credit rating agency
SEC	U.S. Securities and Exchange Commission
SERP	Supplemental Executive Retirement Plan
SO2	Sulfur dioxide
STIP	Short-Term Incentive Plan
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
CLECO POWER	2017 1ST 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 1ST 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 “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.

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 1ST QUARTER FORM 10-Q

PART I — FINANCIAL INFORMATION

ITEM 1.  CONDENSED CONSOLIDATED FINANCIAL STATEMENTS (UNAUDITED)

Cleco Holdings

These unaudited Condensed Consolidated Financial Statements should be read in conjunction with Cleco Holdings’ 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
CLECO POWER	2017 1ST QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Income (Unaudited)
	SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED  MAR. 31, 2017			FOR THE THREE MONTHS ENDED  MAR. 31, 2016
Operating revenue
Electric operations	$	234,056		$	250,157
Other operations	16,880			17,132
Gross operating revenue	250,936			267,289
Electric customer credits	(435		)	(321		)
Operating revenue, net	250,501			266,968
Operating expenses
Fuel used for electric generation	69,873			87,443
Power purchased for utility customers	31,963			23,105
Other operations	31,892			29,325
Maintenance	24,523			24,631
Depreciation and amortization	40,851			38,938
Taxes other than income taxes	12,502			12,907
Merger transaction and commitment costs	99			1,522
Gain on sale of asset	—			(1,095		)
Total operating expenses	211,703			216,776
Operating income	38,798			50,192
Interest income	312			224
Allowance for equity funds used during construction	911			652
Other income	1,370			506
Other expense	(274		)	(516		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	31,945			19,738
Allowance for borrowed funds used during construction	(227		)	(185		)
Total interest charges	31,718			19,553
Income before income taxes	9,399			31,505
Federal and state income tax expense	3,107			12,137
Net income	$	6,292		$	19,368
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO
CLECO POWER	2017 1ST QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Net income	$	6,292		$	19,368
Other comprehensive (loss) income, net of tax
Postretirement benefits (loss) gain (net of tax benefit of $1,370 in 2017 and tax expense of $330 in 2016)	(2,191		)	528
Net gain on cash flow hedges (net of tax expense of $33 in 2016)	—			53
Total other comprehensive (loss) income, net of tax	(2,191		)	581
Comprehensive income, net of tax	$	4,101		$	19,949
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO
CLECO POWER	2017 1ST QUARTER FORM 10-Q

CLECO
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT MAR. 31, 2017			AT DEC. 31, 2016
Assets
Current assets
Cash and cash equivalents	$	21,519		$	23,077
Restricted cash and cash equivalents	14,150			23,084
Customer accounts receivable (less allowance for doubtful accounts of $8,056 in 2017 and $7,199 in 2016)	45,342			56,780
Other accounts receivable	21,191			19,778
Unbilled revenue	29,504			34,268
Fuel inventory, at average cost	52,658			46,410
Materials and supplies, at average cost	83,301			81,818
Energy risk management assets	4,957			7,884
Accumulated deferred fuel	24,212			20,787
Cash surrender value of company-/trust-owned life insurance policies	78,927			77,225
Prepayments	7,497			7,813
Regulatory assets	26,476			26,803
Other current assets	423			1,315
Total current assets	410,157			427,042
Property, plant, and equipment
Property, plant, and equipment	3,506,239			3,476,581
Accumulated depreciation	(98,969		)	(75,816		)
Net property, plant, and equipment	3,407,270			3,400,765
Construction work in progress	99,113			78,577
Total property, plant, and equipment, net	3,506,383			3,479,342
Equity investment in investee	18,672			18,672
Goodwill	1,490,797			1,490,797
Prepayments	4,874			4,731
Restricted cash and cash equivalents	23,554			23,410
Regulatory assets - deferred taxes, net	238,378			237,449
Regulatory assets	445,200			454,644
Net investment in direct financing lease	13,407			13,420
Intangible assets	135,591			142,634
Tax credit fund investment, net	12,138			11,888
Other deferred charges	36,830			39,115
Total assets	$	6,335,981		$	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
CLECO POWER	2017 1ST QUARTER FORM 10-Q

CLECO
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT MAR. 31, 2017			AT DEC. 31, 2016
Liabilities and member’s equity
Liabilities
Current liabilities
Short-term debt	$	541		$	—
Long-term debt due within one year	19,689			19,715
Accounts payable	95,307			112,087
Customer deposits	56,972			56,599
Provision for rate refund	3,262			3,974
Provision for merger commitments	10,999			14,371
Taxes payable	16,510			3,942
Interest accrued	40,447			14,783
Energy risk management liabilities	539			201
Deferred compensation	10,787			11,654
Other current liabilities	14,922			14,850
Total current liabilities	269,975			252,176
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	1,035,656			1,033,055
Accumulated deferred investment tax credits	2,585			2,751
Postretirement benefit obligations	227,777			223,003
Restricted storm reserve	17,643			17,385
Other deferred credits	33,740			29,440
Total long-term liabilities and deferred credits	1,317,401			1,305,634
Long-term debt, net	2,726,696			2,738,571
Total liabilities	4,314,072			4,296,381
Commitments and contingencies (Note 12)
Member’s equity
Membership interest	2,040,421			2,069,376
Accumulated deficit	(17,821		)	(24,113		)
Accumulated other comprehensive (loss) income	(691		)	1,500
Total member’s equity	2,021,909			2,046,763
Total liabilities and member’s equity	$	6,335,981		$	6,343,144
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO
CLECO POWER	2017 1ST QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Cash Flows (Unaudited)
	SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Operating activities
Net income	$	6,292		$	19,368
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	46,727			40,285
Gain on sale of asset	—			(1,095		)
Allowance for equity funds used during construction	(911		)	(652		)
Deferred income taxes	3,041			8,770
Deferred fuel costs	(2,982		)	719
Cash surrender value of company-/trust-owned life insurance	(1,702		)	(484		)
Changes in assets and liabilities
Accounts receivable	8,346			3,129
Unbilled revenue	4,765			1,207
Fuel inventory and materials and supplies	(7,733		)	17,725
Prepayments	1,318			2,076
Accounts payable	(27,148		)	(21,379		)
Customer deposits	2,622			2,877
Provision for merger commitments	(3,866		)	—
Postretirement benefit obligations	1,213			2,630
Regulatory assets and liabilities, net	2,599			4,582
Other deferred accounts	1,920			5,529
Taxes accrued	12,568			12,651
Interest accrued	25,620			16,037
Other operating	2,093			2,257
Net cash provided by operating activities	74,782			116,232
Investing activities
Additions to property, plant, and equipment	(47,890		)	(35,476		)
Allowance for equity funds used during construction	911			652
Proceeds from sale of property	242			1,909
Contributions to equity investment in investee	—			(2,450		)
Transfer of cash from restricted accounts, net	8,790			4,088
Other investing	(165		)	43
Net cash used in investing activities	(38,112		)	(31,234		)
Financing activities
Draws on credit facilities	—			3,000
Payments on credit facilities	—			(10,000		)
Repayment of long-term debt	(9,060		)	(8,546		)
Dividends paid on common stock	—			(24,579		)
Distributions to member	(28,955		)	—
Other financing	(213		)	(673		)
Net cash used in financing activities	(38,228		)	(40,798		)
Net (decrease) increase in cash and cash equivalents	(1,558		)	44,200
Cash and cash equivalents at beginning of period	23,077			68,246
Cash and cash equivalents at end of period	$	21,519		$	112,446
Supplementary cash flow information
Interest paid, net of amount capitalized	$	4,011		$	2,460
Income taxes paid (refunded), net	$	1		$	(481	)
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	27,617		$	11,874
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO
CLECO POWER	2017 1ST QUARTER FORM 10-Q

CLECO
Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited)
(THOUSANDS)	MEMBERSHIP INTEREST			ACCUMULATED DEFICIT			AOCI			TOTAL MEMBER’S EQUITY
Balances, Dec. 31, 2016	$	2,069,376		$	(24,113	)	$	1,500		$	2,046,763
Distributions to member	(28,955		)	—			—			(28,955		)
Net income	—			6,292			—			6,292
Other comprehensive loss, net of tax	—			—			(2,191		)	(2,191		)
Balances, Mar. 31, 2017	$	2,040,421		$	(17,821	)	$	(691	)	$	2,021,909
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

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CLECO POWER	2017 1ST 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
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017			2016
Operating revenue
Electric operations	$	237,553		$	250,157
Other operations	16,365			16,614
Affiliate revenue	219			232
Gross operating revenue	254,137			267,003
Electric customer credits	(435		)	(321		)
Operating revenue, net	253,702			266,682
Operating expenses
Fuel used for electric generation	69,873			87,443
Power purchased for utility customers	31,963			23,105
Other operations	31,988			29,399
Maintenance	24,420			24,538
Depreciation and amortization	38,758			38,603
Taxes other than income taxes	12,000			12,424
Gain on sale of asset	—			(1,095		)
Total operating expenses	209,002			214,417
Operating income	44,700			52,265
Interest income	266			179
Allowance for equity funds used during construction	911			652
Other income	210			148
Other expense	(274		)	(517		)
Interest charges
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	18,331			19,470
Allowance for borrowed funds used during construction	(227		)	(185		)
Total interest charges	18,104			19,285
Income before income taxes	27,709			33,442
Federal and state income tax expense	9,855			12,563
Net income	$	17,854		$	20,879
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 THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017			2016
Net income	$	17,854		$	20,879
Other comprehensive (loss) income, net of tax
Postretirement benefits (loss) gain (net of tax benefit of $262 in 2017 and tax expense of $125 in 2016)	(420		)	200
Net gain on cash flow hedges (net of tax expense of $33 in 2017 and 2016)	53			53
Total other comprehensive (loss) income, net of tax	(367		)	253
Comprehensive income, net of tax	$	17,487		$	21,132
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 MAR. 31, 2017			AT DEC. 31, 2016
Assets
Utility plant and equipment
Property, plant, and equipment	$	4,815,466		$	4,790,565
Accumulated depreciation	(1,634,875		)	(1,618,241		)
Net property, plant, and equipment	3,180,591			3,172,324
Construction work in progress	97,776			77,306
Total utility plant and equipment, net	3,278,367			3,249,630
Current assets
Cash and cash equivalents	21,164			21,482
Restricted cash and cash equivalents	14,150			23,084
Customer accounts receivable (less allowance for doubtful accounts of $8,056 in 2017 and $7,199 in 2016)	45,342			56,780
Accounts receivable - affiliate	1,378			1,406
Other accounts receivable	21,161			19,457
Taxes receivable, net	721			12,490
Unbilled revenue	29,504			34,268
Fuel inventory, at average cost	52,658			46,410
Materials and supplies, at average cost	83,301			81,818
Energy risk management assets	4,957			7,884
Accumulated deferred fuel	24,212			20,787
Cash surrender value of company-owned life insurance policies	20,090			20,018
Prepayments	5,969			5,892
Regulatory assets	17,618			17,721
Other current assets	—			577
Total current assets	342,225			370,074
Equity investment in investee	18,672			18,672
Prepayments	4,874			4,731
Restricted cash and cash equivalents	23,533			23,389
Regulatory assets - deferred taxes, net	238,378			237,449
Regulatory assets	261,858			268,016
Intangible asset	54,991			58,473
Other deferred charges	34,808			37,014
Total assets	$	4,257,706		$	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 MAR. 31, 2017		AT DEC. 31, 2016
Liabilities and member’s equity
Member’s equity	$	1,517,689	$	1,535,202
Long-term debt, net	1,226,095		1,235,056
Total capitalization	2,743,784		2,770,258
Current liabilities
Long-term debt due within one year	19,689		19,715
Accounts payable	88,994		101,874
Accounts payable - affiliate	9,367		7,190
Customer deposits	56,972		56,599
Provision for rate refund	3,262		3,974
Provision for merger commitments	10,999		14,371
Interest accrued	21,371		7,141
Energy risk management liabilities	539		201
Other current liabilities	10,004		9,951
Total current liabilities	221,197		221,016
Commitments and contingencies (Note 12)
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	1,079,427		1,068,592
Accumulated deferred investment tax credits	2,585		2,751
Postretirement benefit obligations	161,257		159,107
Restricted storm reserve	17,643		17,385
Other deferred credits	31,813		28,339
Total long-term liabilities and deferred credits	1,292,725		1,276,174
Total liabilities and member’s equity	$	4,257,706	$	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 THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017			2016
Operating activities
Net income	$	17,854		$	20,879
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation and amortization	40,871			39,774
Gain on sale of asset	—			(1,095		)
Allowance for equity funds used during construction	(911		)	(652		)
Deferred income taxes	10,135			1,854
Deferred fuel costs	(2,982		)	719
Changes in assets and liabilities
Accounts receivable	8,064			3,130
Accounts and notes receivable, affiliate	471			1,716
Unbilled revenue	4,765			1,207
Fuel inventory and materials and supplies	(7,733		)	17,725
Prepayments	925			1,560
Accounts payable	(23,836		)	(20,581		)
Accounts and notes payable, affiliate	2,083			731
Customer deposits	2,622			2,877
Provision for merger commitments	(3,866		)	—
Postretirement benefit obligations	1,026			1,189
Regulatory assets and liabilities, net	2,103			4,582
Other deferred accounts	1,494			5,529
Taxes accrued	11,769			10,859
Interest accrued	14,230			16,078
Other operating	2,095			2,176
Net cash provided by operating activities	81,179			110,257
Investing activities
Additions to property, plant, and equipment	(46,744		)	(35,453		)
Allowance for equity funds used during construction	911			652
Proceeds from sale of property	242			1,909
Contributions to equity investment in investee	—			(2,450		)
Transfer of cash from restricted accounts, net	8,790			4,088
Other investing	39			43
Net cash used in investing activities	(36,762		)	(31,211		)
Financing activities
Repayment of long-term debt	(9,060		)	(8,546		)
Distributions to parent	(35,000		)	(25,000		)
Other financing	(675		)	(657		)
Net cash used in financing activities	(44,735		)	(34,203		)
Net (decrease) increase in cash and cash equivalents	(318		)	44,843
Cash and cash equivalents at beginning of period	21,482			65,705
Cash and cash equivalents at end of period	$	21,164		$	110,548
Supplementary cash flow information
Interest paid, net of amount capitalized	$	2,212		$	2,334
Income taxes refunded, net	$	—		$	(485	)
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	27,493		$	11,849
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	(35,000		)	—			(35,000		)
Net income	17,854			—			17,854
Other comprehensive loss, net of tax	—			(367		)	(367		)
Balances, Mar. 31, 2017	$	1,531,478		$	(13,789	)	$	1,517,689
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

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 and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Basis of Presentation

The Condensed Consolidated Financial Statements of Cleco Holdings 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 present the financial position and results of operations of Cleco. Amounts reported in Cleco’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 $1.00per 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.

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.

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

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,432	$	9,213
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	9,518		12,671
Total current	14,150		23,084
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	17,576		17,379
Cleco Power’s charitable contributions	4,126		4,179
Cleco Power’s rate credit escrow	1,831		1,831
Total non-current	23,554		23,410
Total restricted cash and cash equivalents	$	37,704	$	46,494

Cleco Power
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,432	$	9,213
Charitable contributions	1,200		1,200
Rate credit escrow	9,518		12,671
Total current	14,150		23,084
Non-current
Future storm restoration costs	17,576		17,379
Charitable contributions	4,126		4,179
Rate credit escrow	1,831		1,831
Total non-current	23,533		23,389
Total restricted cash and cash equivalents	$	37,683	$	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 March 31, 2017, was due to Cleco Katrina/Rita using $9.1 million for scheduled storm recovery bond principal payments and $1.9 million for related interest payments, partially offset by collections of $5.2 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. On April 25, 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. On April 28, 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 March 31, 2017, $0.7 million of the charitable contributions and $124.7 million of the rate credits had been remitted 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 is currently scheduled to be submitted to the LPSC by June 30, 2017. There were no open natural gas positions at March 31, 2017, or December 31, 2016.

Cleco Power purchases the majority of its FTRs in annual auctions facilitated by MISO during the second quarter of each year and may also purchase additional FTRs in monthly auctions facilitated by MISO. 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 initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period 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 March 31, 2017, Cleco Power’s Condensed Consolidated Balance Sheets reflected the fair value of open FTR positions of $5.0 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

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credit exposure, and aggregate counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits, or letters of credit from counterparties or their affiliates, as deemed necessary. Cleco Power has agreements in place with various counterparties that authorize the netting of financial buys and sells and contract payments to mitigate credit risk for transactions entered into for risk management purposes.

Cleco and Cleco Power may enter into contracts to mitigate the volatility in interest rate risk. These contracts include, but are not limited to, interest rate swaps and treasury rate locks. For the successor period for the three months ended March 31, 2017, and for the predecessor period for the three months ended March 31, 2016, Cleco did not enter into any contracts to mitigate the volatility in interest rate risk. For the three months ended March 31, 2017, and 2016, Cleco Power 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, the ESPP and the LTIP 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 March 31, 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 March 31, 2016, Cleco reported pretax compensation expense of $1.0 million on non-vested stock with a related tax benefit of $0.4 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 three months ended March 31, 2016, Cleco Power reported pretax compensation expense of $0.4 million on non-vested stock with a related tax benefit of $0.1 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 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

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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/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. In November and December 2016, Cleco Power redeemed $60.0 million and $250.0 million in long-term debt, respectively. As a result, the fair value adjustments for the

redeemed long-term debt and the related unamortized debt issuance cost of $19.8 million on Cleco’s Consolidated Balance Sheet were derecognized. The offset was to the respective regulatory assets.

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 first quarter of 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 the ability to recognize revenue in situations where collectability is in question. Management will

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continue to evaluate the impact of this guidance, including additional clarifying amendments issued following the date of initial issuance. The amended guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants.

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. Early adoption is permitted. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes practical expedients that may be elected by entities. Management will continue to evaluate the impact of this guidance. The amended guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants.

In November 2016, FASB amended guidance for certain cash flow issues. The amended guidance requires that a statement of cash 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 reporting periods within those fiscal years. Early adoption is permitted. 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 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 is evaluating the impact that the adoption of this guidance will have 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 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 is currently evaluating the impact of this standard, including coordinating with its industry group as well as its advisors. The adoption of this guidance could have a material 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 MAR. 31, 2017		AT DEC. 31, 2016
Regulatory assets – deferred taxes, net	$	238,378	$	237,449
Mining costs	5,735		6,372
Interest costs	4,770		4,860
AROs	2,252		2,096
Postretirement costs	142,873		145,268
Tree trimming costs	5,874		5,549
Training costs	6,669		6,708
Surcredits, net	5,028		5,876
AMI deferred revenue requirement	4,636		4,772
Production operations and maintenance expenses	12,551		13,999
AFUDC equity gross-up	70,185		70,423
Acadia Unit 1 acquisition costs	2,415		2,442
Financing costs	8,570		8,663
Biomass costs	11		18
MISO integration costs	1,170		1,404
Coughlin transaction costs	991		999
Corporate franchise tax	654		1,308
MATS costs	4,501		4,270
Other	591		710
Total regulatory assets	279,476		285,737
Fuel and purchased power	24,212		20,787
Total regulatory assets, net	$	542,066	$	543,973

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

(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Total Cleco Power regulatory assets, net (1)	$	542,066	$	543,973
Cleco Holdings’ Merger adjustments
Fair value of long-term debt	153,479		155,776
Postretirement costs	22,866		23,362
Financing costs	8,880		8,966
Debt issuance costs	6,975		7,606
Total Cleco regulatory assets, net	$	734,266	$	739,683

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

of the Merger.

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 will be 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 will be amortized over the terms of the related debt issuances. In November and December 2016, Cleco Power redeemed $60.0 million and $250.0 million in long-term debt, respectively. As a result, the fair value adjustments for the redeemed long-term debt and the related unamortized debt issuance cost of $19.8 million on Cleco’s Consolidated Balance Sheets 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 March 31, 2017, and December 31, 2016, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, and accounts payable approximate fair value because of their short-term nature.

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

Cleco
	AT MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,756,889	$	2,766,056	$	2,768,149	$	2,754,518

* The carrying value of long-term debt does not include deferred issuance costs of $11.7 million at March 31, 2017, and $11.7 million at December 31, 2016.

Cleco Power
	AT MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,253,410	$	1,418,027	$	1,262,373	$	1,418,693

* The carrying value of long-term debt does not include deferred issuance costs of $8.8 million at March 31, 2017, and $9.4 million at December 31, 2016.

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 MAR. 31, 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	$	56,624	$	—	$	56,624	$	—	$	66,410	$	—	$	66,410	$	—
FTRs	4,957		—		—		4,957		7,884		—		—		7,884
Total assets	$	61,581	$	—	$	56,624	$	4,957	$	74,294	$	—	$	66,410	$	7,884
Liability description
FTRs	539		—		—		539		201		—		—		201
Total liabilities	$	539	$	—	$	—	$	539	$	201	$	—	$	—	$	201

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Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT MAR. 31, 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	$	56,598	$	—	$	56,598	$	—	$	65,089	$	—	$	65,089	$	—
FTRs	4,957		—		—		4,957		7,884		—		—		7,884
Total assets	$	61,555	$	—	$	56,598	$	4,957	$	72,973	$	—	$	65,089	$	7,884
Liability description
FTRs	539		—		—		539		201		—		—		201
Total liabilities	$	539	$	—	$	—	$	539	$	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 MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Beginning balance	$	7,683		$	7,398
Unrealized gains (losses)*	2,104			(832		)
Purchases	275			46
Settlements	(5,644		)	(4,746		)
Ending balance	$	4,418		$	1,866
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet.

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017			2016
Beginning balance	$	7,683		$	7,398
Unrealized gains (losses)*	2,104			(832		)
Purchases	275			46
Settlements	(5,644		)	(4,746		)
Ending balance	$	4,418		$	1,866
* 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 March 31, 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 Mar. 31, 2017	$	4,957	$	539	RTO auction pricing	FTR price - per MWh	$	(3.25	)	$	6.63
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. 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. Cleco has consistently applied the Level 2 fair value technique from fiscal period to fiscal period. 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 and therefore RTO auction prices are used. Significant increases or decreases in any of those inputs in isolation would result in a significantly different fair value measurement.

The assets and liabilities reported at fair value are grouped into classes based on the underlying nature and risks associated with the individual asset or liability.

At March 31, 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 $19.0 million, $14.1 million, and $23.5 million, respectively, at March 31, 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 $19.0 million, $14.1 million, and $23.5 million, respectively, at March 31, 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.

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FTRs are categorized as Level 3 fair value measurements because the only relevant pricing available comes from MISO auctions, which occur monthly in the Multi-Period Monthly Auction.

During the three months ended March 31, 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 March 31, 2017, and December 31, 2016:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT MAR. 31, 2017		AT DEC. 31, 2016
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	4,957	$	7,884
Current	Energy risk management liabilities	539		201
Commodity-related contracts, net		$	4,418	$	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 three months ended March 31, 2017, and 2016:

Cleco
	AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		SUCCESSOR			PREDECESSOR
(THOUSANDS)	DERIVATIVES LINE ITEM	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Commodity contracts
FTRs(1)	Electric operations	$	9,163		$	8,520
FTRs(1)	Power purchased for utility customers	(4,665		)	(5,723		)
Total		$	4,498		$	2,797

⁽¹⁾ For the period January 1, 2017 - March 31, 2017, unrealized gains associated with FTRs not recognized in income on derivatives of $2.1 million were reported through Accumulated deferred fuel on the balance sheet. For the period January 1, 2016 - March 31, 2016, unrealized losses associated with FTRs not recognized in income on derivatives of $0.8 million were reported through Accumulated deferred fuel on the balance sheet.

Cleco Power
	AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	DERIVATIVES LINE ITEM	2017			2016
Commodity contracts
FTRs(1)	Electric operations	$	9,163		$	8,520
FTRs(1)	Power purchased for utility customers	(4,665		)	(5,723		)
Total		$	4,498		$	2,797

⁽¹⁾ For the three months ended March 31, 2017, and 2016, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $2.1 million and ($0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

At March 31, 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 is currently scheduled to be submitted to the LPSC by June 30, 2017.

Cleco Power purchases the majority of its FTRs in annual auctions facilitated by MISO during the second quarter of each year and may also purchase additional FTRs in monthly auctions facilitated by MISO. 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 March 31, 2017, and December 31, 2016, was 3.6 million MWh and 9.0 million MWh, respectively.

Note 6 — Debt

On May 17, 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% senior notes due May 1, 2026, and 4.973% senior notes due May 1, 2046, 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

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other benefits during the periods in which the benefits are earned.

The components of net periodic pension and other benefit cost for the three months ended March 31, 2017, and 2016 are as follows:

	PENSION BENEFITS						OTHER BENEFITS
	SUCCESSOR			PREDECESSOR			SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016			FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Components of periodic benefit costs
Service cost	$	2,225		$	2,262		$	385		$	380
Interest cost	5,358			5,507			403			420
Expected return on plan assets	(6,138		)	(6,010		)	—			—
Amortizations
Prior period service (credit) cost	(18		)	(18		)	—			30
Net loss (gain)	2,413			2,469			(3		)	160
Net periodic benefit cost	$	3,840		$	4,210		$	785		$	990

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 successor period January 1, 2017, through March 31, 2017, was $0.4 million. The amount for the predecessor period for the three months ended March 31, 2016, was $0.4 million.

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 months ended March 31, 2017, was $0.9 million. The amount for the same period in 2016 was $0.8 million. The current and non-current portions of the other benefits liability for Cleco and Cleco Power at March 31, 2017, and December 31, 2016, are as follows:

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	3,854	$	3,854
Non-current	$	39,934	$	40,196

Cleco Power
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	3,345	$	3,345
Non-current	$	34,668	$	34,892

SERP

Certain Cleco officers are covered by SERP. 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 limits of the 401(k) Plan. Two 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. 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 above. 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. 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 designated as the beneficiary for life insurance policies issued on SERP participants. 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.

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The components of net periodic benefit cost related to SERP for the three months ended March 31, 2017, and 2016 are as follows:

	SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Components of periodic benefit costs
Service cost	$	145		$	583
Interest cost	800			731
Amortizations
Prior period service (credit) cost	(57		)	13
Net loss	419			655
Net periodic benefit cost	1,307			1,982
Special/contractual termination benefits	315			—
Total benefit cost	$	1,622		$	1,982

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 special termination benefits of $0.3 million.

The total expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income was $0.3 million for the three months ended March 31, 2017, compared to $0.4 million for the same period in 2016.

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

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	4,308	$	4,308
Non-current	$	77,329	$	73,738

Cleco Power
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	885	$	885
Non-current	$	16,075	$	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 can be made in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Prior to the close of the Merger on April 13, 2016, employer contributions could also be in the form of Cleco Corporation common stock. 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 monthsended March 31, 2017, and 2016 is as follows:

	SUCCESSOR		PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
401(k) Plan expense	$	1,668	$	1,374

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three months ended March 31, 2017, and 2016 is as follows:

	SUCCESSOR		PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
401(k) Plan expense	$	279	$	282

Note 8 — Income Taxes

Effective Tax Rates

The following tables summarize the effective income tax rates for Cleco and Cleco Power for the three months ended March 31, 2017, and 2016:

Cleco
	SUCCESSOR		PREDECESSOR
	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
Effective tax rate	33.1	%	38.5	%

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31,
	2017		2016
Effective tax rate	35.6	%	37.6	%

For the successor period, the effective income tax rate for Cleco was 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 rate for Cleco was 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 months ended March 31, 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.

Valuation Allowance

Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a tax benefit will not be realized. As of March 31, 2017, and December 31, 2016, Cleco had a deferred tax asset resulting from NMTC carryforwards of $97.5 million. If the NMTC carryforwards are not utilized, they will begin to expire in 2029. Management considers it more likely than not that all deferred tax assets related to NMTC carryforwards will be realized; therefore, no valuation allowance has been recorded.

Net Operating Losses

As of March 31, 2017, Cleco has a federal net operating loss carryforward of $82.1 million and a state net operating loss carryforward of $193.1 million. The federal and state net operating loss carryforwards will begin to expire in 2031. Cleco considers it more likely than not that these income tax losses

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will be utilized to reduce future income tax payments and Cleco expects to utilize the entire net operating loss carryforward within the statutory deadlines.

Uncertain Tax Positions

Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. At March 31, 2017, and December 31, 2016, Cleco and Cleco Power had no interest payable related to uncertain tax positions. For the three months ended March 31, 2017, and 2016, Cleco and Cleco Power had no interest expense related to uncertain tax positions.

At March 31, 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 March 31, 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, and 2015. The IRS has concluded its audit for the years 2010 through 2014.

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 three months ended March 31, 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 provided by Support Group.

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MAR. 31,
	SUCCESSOR
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	237,553		$	(3,497	)	$	—		$	234,056
Other operations	16,365			515			—			16,880
Electric customer credits	(435		)	—			—			(435		)
Affiliate revenue	219			14,734			(14,953		)	—
Operating revenue, net	$	253,702		$	11,752		$	(14,953	)	$	250,501
Depreciation and amortization	$	38,758		$	2,093		$	—		$	40,851
Merger transaction and commitment costs	$	—		$	99		$	—		$	99
Interest charges	$	18,104		$	13,681		$	(67	)	$	31,718
Interest income	$	266		$	113		$	(67	)	$	312
Federal and state income tax expense (benefit)	$	9,855		$	(6,748	)	$	—		$	3,107
Net income (loss)	$	17,854		$	(11,562	)	$	—		$	6,292
Additions to property, plant, and equipment	$	46,744		$	1,146		$	—		$	47,890
Equity investment in investees	$	18,672		$	—		$	—		$	18,672
Goodwill	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets	$	5,748,503		$	621,406		$	(33,928	)	$	6,335,981

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	PREDECESSOR
2016 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	250,157		$	—		$	—		$	250,157
Other operations	16,614			518			—			17,132
Electric customer credits	(321		)	—			—			(321		)
Affiliate revenue	232			13,024			(13,256		)	—
Operating revenue, net	$	266,682		$	13,542		$	(13,256	)	$	266,968
Depreciation and amortization	$	38,603		$	335		$	—		$	38,938
Merger transaction costs	$	—		$	1,539		$	(17	)	$	1,522
Interest charges	$	19,285		$	278		$	(10	)	$	19,553
Interest income	$	179		$	55		$	(10	)	$	224
Federal and state income tax expense (benefit)	$	12,563		$	(426	)	$	—		$	12,137
Net income (loss)	$	20,879		$	(1,511	)	$	—		$	19,368
Additions to property, plant, and equipment	$	35,453		$	23		$	—		$	35,476
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 (Successor)

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, is for the period November 2013 through February 2015. On September 29, 2016, FERC issued a Final Order in response to the first complaint establishing a 10.32% ROE.

The second complaint, filed in February 2015, is 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 ofMarch 31, 2017, Cleco Power had$1.9 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 must file annual monitoring reports no later than October 31 for the 12-month period ended June 30. Cleco Power was scheduled to file an application with the LPSC for a new FRP by June 30, 2017. However, as part of the merger approval process Cleco Power agreed not to file an application for a new FRP or

request an increase in base rates until June 30, 2019, with anticipated new rates being effective July 1, 2020.

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 May 1, 2017, the LPSC filed the report of its review of the 2016 FRP monitoring report which confirmed no earnings-related refunds. The report is expected to be approved in June 2017. For more information on Merger Commitments, see “— Merger Commitments.”

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 March 31, 2017, Cleco Power had issued $125.0 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 or another state agency, 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 savings are not subject to the target ROE or any sharing mechanism in the current FRP and will continue until Cleco Power files for a new FRP in 2019. The cost savings will be refunded to customers annually beginning in September 2017. As of March 31, 2017, Cleco Power had $1.2 million accrued for the cost savings refund. 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.

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Other

On April 8, 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. On April 8, 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. On October 4, 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 anticipates the completion of this agreement in the second half of 2017.

Note 11 — Variable Interest Entities

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

Oxbow is owned 50% by Cleco Power and 50% by SWEPCO. Cleco Power is not the primary beneficiary because it shares the power to control Oxbow’s significant activities with SWEPCO. Cleco Power’s current assessment of its maximum exposure to loss related to Oxbow at March 31, 2017, consisted of its equity investment of $18.7 million.

During the first quarter of 2017, the transition from the Dolet Hills mine to the Oxbow mine commenced. This transition is expected to be completed in the third quarter of 2017.

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

INCEPTION TO DATE (THOUSANDS)	AT MAR. 31, 2017			AT DEC. 31, 2016
Purchase price	$	12,873		$	12,873
Cash contributions	6,399			6,399
Dividend received	(600		)	(600		)
Total equity investment in investee	$	18,672		$	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 MAR. 31, 2017		AT DEC. 31, 2016
Oxbow’s net assets/liabilities	$	37,345	$	37,345
Cleco Power’s 50% equity	$	18,672	$	18,672
Cleco Power’s maximum exposure to loss	$	18,672	$	18,672

The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017		2016
Operating revenue	$	1,073	$	2,101
Operating expenses	1,073		2,101
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

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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. 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.

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 on November 9, 2016. The Third Circuit Court of Appeal issued a schedule requiring plaintiffs to file their brief on April 18, 2017, with Cleco’s brief due on May 4, 2017. The plaintiffs have requested an extension of the briefing schedule. Cleco anticipates the plaintiffs’ brief will be due on May 18, 2017, with Cleco’s brief

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being due on June 7, 2017, pending any requests for extension.

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. On January 21, 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. On June 30, 2016, the Third Circuit Court of Appeal for the State of Louisiana denied the request to have the case dismissed. On July 29, 2016, Cleco filed a writ to the Louisiana Supreme Court seeking a review of the District Court’s denial of Cleco’s exception. On November 15, 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. On May 16, 2016, the District Court lifted the stay at the request of Gulf Coast. 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.

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

LPSC Audits

Fuel Audit

Generally, the cost of fuel used for electric generation and the cost of power purchased for utility customers are recovered through the LPSC-established FAC that enables Cleco Power to pass on to its customers substantially all such charges. Recovery of FAC costs is subject to periodic fuel audits by the LPSC. The LPSC FAC General Order issued in November 1997, in Docket No. U-21497 provides that an audit of FAC filings will be performed at least every other year. On February 3, 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. On February 3, 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 this audit was $81.2 million. On December 1, 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.

Cleco Power began incurring additional environmental compliance expenses in the second quarter of 2015 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. On April 15, 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. These expenses are also eligible for recovery through Cleco Power’s EAC and are subject to periodic review by the LPSC.

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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, is for the period November 2013 through February 2015. On September 29, 2016, FERC issued a Final Order in response to the first complaint establishing a 10.32% ROE.

In February 2015, a second ROE complaint was filed 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 March 31, 2017, Cleco Power had $1.9 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 March 31, 2017, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters is $4.8 million and has accrued this amount.

Off-Balance Sheet Commitments and Guarantees

Cleco Holdings and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and 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 these 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. At March 31, 2017, 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. At March 31, 2017, 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.

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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 on Cleco’s Condensed Consolidated Balance Sheet in the line item Tax credit fund investment, net. 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 March 31, 2017, was $18.1 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.

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 8, 2016, taking into consideration the anticipated completion of the Merger, S&P and Moody’s downgraded Cleco Holdings’ credit ratings to BBB- (stable) and Baa3 (stable), respectively. On April 8, 2016, taking into consideration the anticipated completion of the Merger, S&P and Moody’s credit ratings were maintained at Cleco Power at BBB+ (stable) and A3 (stable), respectively. On April 7, 2017, Moody’s updated its credit ratings by maintaining Cleco Holdings at Baa3 (stable) and Cleco Power at A3 (stable).

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 MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	1	$	176	$	3	$	119
Support Group	1,377		9,191		1,402		7,071
Other (1)	—		—		1		—
Total	$	1,378	$	9,367	$	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 MAR. 31, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
SUCCESSOR
Balances, beginning of period	$	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 loss	(126		)	—		(126		)
Net current-period other comprehensive loss	(2,191		)	—		(2,191		)
Balances, Mar. 31, 2017	$	(691	)	$	—	$	(691	)

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	FOR THE THREE MONTHS ENDED MAR. 31, 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	528			—			528
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive income	528			53			581
Balances, Mar. 31, 2016	$	(20,329	)	$	(5,675	)	$	(26,004	)

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive income before reclassifications
Postretirement benefit adjustments during the period	(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	164			—			164
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive (loss) income	(420		)	53			(367		)
Balances, Mar. 31, 2017	$	(8,325	)	$	(5,464	)	$	(13,789	)

	FOR THE THREE MONTHS ENDED MAR. 31, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(11,364	)	$	(5,728	)	$	(17,092	)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	200			—			200
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive income	200			53			253
Balances, Mar. 31, 2016	$	(11,164	)	$	(5,675	)	$	(16,839	)

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 months ended March 31, 2017, and March 31, 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

Cleco is currently working on the implementation of a project that is expected to improve its enterprise business applications. The project’s objectives are to gain efficiencies through consistent, industry leading work processes; enable better decision making through data transparency across business functions; mitigate risk through knowledge transfer and better process documentation; provide a modernized,

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flexible platform to support future growth and changing business models; and provide customer-centric focus through technology and flexibility. As of March 31, 2017, Cleco has selected a software enterprise platform and a contract has been signed to acquire licenses for certain software. The total estimated project cost is $130.0 million. The project is expected to be completed in 24 to 36 months, depending on the implementation process selected. Cleco does not expect to implement these systems until 2018 or after. As of March 31, 2017, Cleco had spent $3.6 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 meet increasingly stringent regulatory and environmental standards; and the ability to successfully perform in MISO and the related operating challenges and uncertainties, including increased wholesale competition relative to more suppliers. 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; beginning construction on the Terrebonne to Bayou Vista Transmission project and 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 has been completed 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 $32.3 million. As of March 31, 2017, Cleco Power had spent $26.0 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 with the project expected to be commercially operational by the first quarter of 2018 at an original expected cost of $81.9 million. Based upon new waste heat gas specifications and the associated redesign considerations, as well as other project changes, the project cost estimate has been increased to $99.8 million and will produce an estimated 50,000 more Mwh than original projections. Upon achieving commercial operations, the project is expected to generate more than 300,000 MWh of zero additional carbon emitting energy each year. As of March 31, 2017, Cleco Power had spent $34.3 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 for customers in southeast Louisiana. A line routing study began in March 2016 and permitting and right-of-way acquisition began in May 2016. The project team continues to investigate wetland mitigation options. 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 third quarter of 2018. As of March 31, 2017, Cleco Power had spent $2.5 million on the project.

Coughlin Pipeline Project

The Coughlin Pipeline project includes construction of a pipeline directly connecting the Pine Prairie Energy Center to Cleco’s Coughlin Power Station. The project is expected to increase fuel delivery reliability and mitigate exposure to price increases. Cleco filed a letter with the LPSC seeking guidance on the appropriate treatment and timing of recovering revenue associated with the project. Cleco has responded to its first set of data requests regarding the Coughlin Pipeline project. The estimated cost of the project is $29.4 million with an estimated construction time of 18 months.

Other

Cleco Power is working on securing load growth opportunities that include renewal of existing load through 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 the financial information for Cleco below 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 annual impairment testing. 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.

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Comparison of the Three Months Ended March 31, 2017, and 2016

Cleco Consolidated
	SUCCESSOR		PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
Operating revenue, net	$	250,501	$	266,968
Operating expenses	211,703		216,776
Operating income	$	38,798	$	50,192
Other income	$	1,370	$	506
Interest charges	$	31,718	$	19,553
Federal and state income tax expense	$	3,107	$	12,137
Net income	$	6,292	$	19,368

Cleco’s net income attributable to the successor period for the three months ended March 31, 2017, was $6.3 million. There were no significant changes in the underlying trends impacting net income with the exception of the change in pretax income primarily related to:

• $13.4 million of interest costs related to debt obtained as a result of the Merger,

• $3.5 million of an offset to operating revenue related to the amortization of the intangible asset recorded for the fair value adjustment of wholesale power supply agreements as a result of the Merger, and

• $1.7 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 33.1%.

Cleco’s net income attributable to the predecessor period for the three months ended March 31, 2016, was $19.4 million. There were no significant changes in the underlying trends impacting net income. The effective income tax rate for the period was 38.5%.

The estimated annual effective income tax rate used in the first quarter of 2017 for Cleco might not be indicative of the full-year income tax rate.

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

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2017			2016				VARIANCE			CHANGE
Operating revenue
Base	$	143,117		$	148,820			$	(5,703	)	(3.8	)%
Fuel cost recovery	94,436			101,337				(6,901		)	(6.8	)%
Electric customer credits	(435		)	(321		)		(114		)	(35.5	)%
Other operations	16,365			16,614				(249		)	(1.5	)%
Affiliate revenue	219			232				(13		)	(5.6	)%
Operating revenue, net	253,702			266,682				(12,980		)	(4.9	)%
Operating expenses
Recoverable fuel and power purchased	94,280			101,339				7,059			7.0	%
Non-recoverable fuel and power purchased	7,556			9,209				1,653			17.9	%
Other operations	31,988			29,399				(2,589		)	(8.8	)%
Maintenance	24,420			24,538				118			0.5	%
Depreciation and amortization	38,758			38,603				(155		)	(0.4	)%
Taxes other than income taxes	12,000			12,424				424			3.4	%
Gain on sale of asset	—			(1,095		)		(1,095		)	—	%
Total operating expenses	209,002			214,417				5,415			2.5	%
Operating income	$	44,700		$	52,265			$	(7,565	)	(14.5	)%
Interest charges	$	18,104		$	19,285			$	1,181		6.1	%
Federal and state income tax expense	$	9,855		$	12,563			$	2,708		21.6	%
Net income	$	17,854		$	20,879			$	(3,025	)	(14.5	)%

Cleco Power’s net income in the first quarter of 2017 decreased $3.0 million compared to the first quarter of 2016 largely as a result of the following factors:

• lower base revenue,

• higher other operations expense, and

• absence of a gain on sale of asset.

These factors were partially offset by:

• lower income taxes,

• lower non-recoverable fuel and power purchased, and

• lower interest charges.

The following tables show the components of Cleco Power’s base revenue:

	FOR THE THREE MONTHS ENDED MAR. 31,
(MILLION kWh)	2017	2016	FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	711	797		(10.8	)%
Commercial	584	571		2.3	%
Industrial	488	449		8.7	%
Other retail	31	31		—	%
Total retail	1,814	1,848		(1.8	)%
Sales for resale	629	724		(13.1	)%
Total retail and wholesale customer sales	2,443	2,572		(5.0	)%

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	FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017		2016		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	55,028	$	60,105		(8.4	)%
Commercial	45,467		45,237			0.5	%
Industrial	20,719		21,098			(1.8	)%
Other retail	2,560		2,565			(0.2	)%
Surcharge	5,082		5,121			(0.8	)%
Total retail	128,856		134,126			(3.9	)%
Sales for resale	14,261		14,694			(2.9	)%
Total retail and wholesale customer sales	$	143,117	$	148,820		(3.8	)%

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 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 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 cooling and heating degree-days.

	FOR THE THREE MONTHS ENDED MAR. 31,
				2017 CHANGE
	2017	2016	NORMAL	PRIOR YEAR		NORMAL
Heating degree-days	421	740	890	(43.1	)%	(52.7	)%
Cooling degree-days	232	119	78	95.0	%	197.4	%

Base

Base revenue decreased $5.7 million during the first quarter of 2017 compared to the first quarter of 2016 primarily due to $4.4 million of lower usage as a result of milder winter weather and lower sales to wholesale customers, and $1.3 million driven by lower rates to a site specific industrial customer.

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 75% of Cleco Power’s total fuel cost during the first 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 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 the fuel audit, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation — LPSC Audits — Fuel Audit.”

Other Operations Revenue

Other operations revenue decreased $0.2 million during the first quarter of 2017 compared to the first quarter of 2016 primarily due to $2.3 million of lower transmission revenue from wholesale customers as a result of issuing customer credits relating to the MISO ROE complaints, partially offset by $2.1 million of higher net transmission and distribution revenue.

Non-recoverable Fuel and Power Purchased

Non-recoverable fuel and power purchased decreased $1.7 million during the first quarter of 2017 compared to the first quarter of 2016 primarily due to a $2.3 million refund from MISO for wholesale customers relating to the MISO ROE complaints, the absence of a reserve for uncollectible expenses of $1.1 million, and $0.1 million of lower miscellaneous expenses. These decreases were partially offset by $1.8 million of higher MISO transmission costs.

Other Operations Expense

Other operations expense increased $2.6 million during the first quarter of 2017 compared to the first quarter of 2016 primarily due to $1.2 million of higher salaries and compensation expenses, $1.2 million of higher fees for outside services, $0.5 million of higher distribution operations expenses, and $0.2 million of higher miscellaneous expenses. These increases were partially offset by $0.5 million of lower pension and SERP expenses.

Gain on Sale of Asset

Gain on sale of asset decreased $1.1 million during the first quarter of 2017 compared to the first quarter of 2016 due to the absence of a gain on the sale of property.

Interest Charges

Interest charges decreased $1.2 million during the first quarter of 2017 compared to the first quarter of 2016 due to long-term debt redemptions in the fourth quarter of 2016.

Income Taxes

Federal and state income tax expense decreased $2.7 million during the first quarter of 2017 compared to the first quarter of 2016 primarily due to $2.0 million for the change in pretax income, excluding AFUDC, $0.4 million for the flowthrough of state tax benefits, and $0.3 million to record tax expense at the projected annual effective tax rate.

The estimated annual effective income tax rate used during the first quarter of 2017 for Cleco Power might not be indicative of the full-year income tax rate.

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FINANCIAL CONDITION

Liquidity and Capital Resources

General Considerations and Credit-Related Risks

Credit Ratings and Counterparties

Financing for operational needs and capital expenditure requirements not satisfied by operating cash flows depends upon the cost and availability of external funds through both short- and long-term financing. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain or expand its businesses. Access to funds is dependent upon factors such as general economic and capital market conditions, 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 March 31, 2017:

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

On April 8, 2016, taking into consideration the anticipated completion of the Merger, S&P and Moody’s downgraded Cleco Holdings’ credit ratings to BBB- (stable) and Baa3 (stable), respectively. On April 8, 2016, taking into consideration the anticipated completion of the Merger, S&P and Moody’s credit ratings were maintained at Cleco Power at BBB+ (stable) and A3 (stable), respectively. On April 7, 2017, Moody’s updated its credit ratings by maintaining Cleco Holdings at Baa3 (stable) and Cleco Power at A3 (stable).

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 March 31, 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.”

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.

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

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,432	$	9,213
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	9,518		12,671
Total current	14,150		23,084
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	17,576		17,379
Cleco Power’s charitable contributions	4,126		4,179
Cleco Power’s rate credit escrow	1,831		1,831
Total non-current	23,554		23,410
Total restricted cash and cash equivalents	$	37,704	$	46,494

Cleco Power
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,432	$	9,213
Charitable contributions	1,200		1,200
Rate credit escrow	9,518		12,671
Total current	14,150		23,084
Non-current
Future storm restoration costs	17,576		17,379
Charitable contributions	4,126		4,179
Rate credit escrow	1,831		1,831
Total non-current	23,533		23,389
Total restricted cash and cash equivalents	$	37,683	$	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 March 31, 2017, was due to Cleco Katrina/Rita using $9.1 million for scheduled storm recovery bond principal payments and $1.9 million for related interest payments, partially offset by collections of $5.2 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. On April 25, 2016, in accordance with the Merger Commitments, Cleco Power established the charitable contribution fund and deposited the rate credit funds into an escrow account. On April 28, 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 March 31, 2017, $0.7 million of the charitable contributions and $124.7 million of the rate credits had been remitted from restricted cash.

Debt

Cleco Consolidated

At March 31, 2017, Cleco had $0.5 million short-term debt outstanding at a rate of 2.73%. This debt was repaid on April 3, 2017. Cleco had no short-term debt outstanding at December 31, 2016.

At March 31, 2017, Cleco’s long-term debt outstanding was $2.75 billion, of which $19.7 million was due within one

year. The long-term debt due within one year at March 31, 2017, represents $18.5 million of principal payments for the Cleco Katrina/Rita storm recovery bonds and $1.2 million of capital lease payments. For Cleco, long-term debt decreased$11.9 million from December 31, 2016, primarily due to $9.1 million in scheduled bond principal payments made in March 2017, $2.3 million in amortization of the merger fair value adjustment of long-term debt, and a $0.7 million decrease in capital lease obligations. These decreases were partially offset by $0.2 million of debt issuance cost and debt discount amortizations.

On May 17, 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% senior notes due May 1, 2026, and 4.973% senior notes due May 1, 2046, 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.

Cash and cash equivalents available at March 31, 2017, were $21.5 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 $421.5 million.

At March 31, 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 March 31, 2017, and December 31, 2016, Cleco had a working capital surplus of $140.2 million and $174.9 million, respectively. The $34.7 milliondecrease in working capital is primarily due to:

• a $25.7 million increase in interest accrued primarily due to accruals for pending interest payments on long-term debt,

• a $12.6 million increase in taxes payable primarily due to accrual of property taxes and payroll taxes,

• an $11.4 million decrease in customer accounts receivable primarily due to a decrease in retail revenue,

• an $8.9 million decrease in current restricted cash and cash equivalents, and

• a $4.8 million decrease in unbilled revenue due to a decrease in customer usage.

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These decreases in working capital were partially offset by:

• a $16.8 million decrease in accounts payable primarily due to the payment of property taxes,

• a $6.2 million increase in fuel inventory primarily due to higher per unit cost of fuel, capitalizing on lower transportation costs, and an early receipt of inventory delivery,

• a $3.4 million increase in accumulated deferred fuel primarily due to surcharge adjustments, partially offset by timing of collections, and

• a $3.4 million decrease in provision for Merger Commitments primarily due to Merger Commitments satisfied during the first quarter of 2017.

Cleco Holdings (Holding Company Level)

Cleco Holdings had $0.5 million short-term debt outstanding at March 31, 2017, at a rate of 2.73%. This debt was repaid on April 3, 2017. Cleco Holdings had no short-term debt outstanding at December 31, 2016.

At March 31, 2017, Cleco Holdings had a $100.0 million credit facility. This facility provides for working capital and other financing needs. At March 31, 2017, Cleco Holdings had no borrowings outstanding under its $100.0 million credit facility.

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 March 31, 2017, were less than $0.1 million, combined with the $100.0 million credit facility capacity for total liquidity of $100.0 million.

Cleco Power

At March 31, 2017, and December 31, 2016, Cleco Power had no short-term debt outstanding.

At March 31, 2017, Cleco Power’s long-term debt outstanding was $1.25 billion, of which $19.7 million was due within one year. The long-term debt due within one year at March 31, 2017, represents $18.5 million of principal payments for the Cleco Katrina/Rita storm recovery bonds and $1.2 million of capital lease payments. For Cleco Power, long-term debt decreased$9.0 million from December 31, 2016, primarily due to $9.1 million in scheduled Cleco Katrina/Rita storm recovery bond principal payments made in March 2017 and a $0.7 million decrease in capital lease obligations. These decreases were partially offset by $0.8 million of debt issuance cost and debt discount amortizations.

At March 31, 2017, Cleco Power had a $300.0 million credit facility. This facility provides for working capital and other financing needs. At March 31, 2017, Cleco Power had no borrowings outstanding under its $300.0 million credit facility.

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 March 31, 2017, were $21.2 million, combined with $300.0 million credit facility capacity for total liquidity of $321.2 million.

At March 31, 2017, and December 31, 2016, Cleco Power had a working capital surplus of $121.0 million and $149.1 million, respectively. The $28.1 milliondecrease in working capital is primarily due to:

• a $14.2 million increase in interest accrued primarily due to accruals for pending interest payments on long-term debt,

• an $11.8 million decrease in taxes receivable primarily due to accrual of property taxes and payroll taxes,

• an $11.4 million decrease in customer accounts receivable primarily due to a decrease in retail revenue,

• an $8.9 million decrease in current restricted cash and cash equivalents, and

• a $4.8 million decrease in unbilled revenue due to a decrease in customer usage.

These decreases in working capital were partially offset by:

• a $12.9 million decrease in accounts payable primarily due to the payment of property taxes,

• a $6.2 million increase in fuel inventory primarily due to higher per unit cost of fuel, capitalizing on lower transportation costs, and an early receipt of inventory delivery,

• a $3.4 million increase in accumulated deferred fuel primarily due to surcharge adjustments, partially offset by timing of collections, and

• a $3.4 million decrease in provision for Merger Commitments primarily due to Merger Commitments satisfied during the first quarter of 2017.

Credit Facilities

At March 31, 2017, Cleco Holdings had a $100.0 million credit facility. The credit facility has various terms, including restricted financial covenants, and expires in 2021. At March 31, 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%. At March 31, 2017, Cleco Holdings had no borrowings outstanding under its $100.0 million credit facility. If Cleco Holdings’ credit ratings were to be downgraded one level by either agency, Cleco 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 March 31, 2017, Cleco Power had a $300.0 million credit facility. The credit facility has various terms, including restricted financial covenants, and expires in 2021. At March 31, 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%. At March 31, 2017, Cleco Power had no borrowings outstanding under its $300.0 million credit facility. 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

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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 March 31, 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 March 31, 2017, was $74.8 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 predecessor period January 1, 2016, through March 31, 2016, was $116.2 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 March 31, 2017, was $38.1 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 predecessor period January 1, 2016, through March 31, 2016, was $31.2 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 March 31, 2017, was $38.2 million. There were no significant changes in the underlying trends impacting cash used in financing activities with the exception of $29.0 million in distributions to Cleco Group. In addition, after the Merger, Cleco Holdings no longer has dividends to stockholders.

Cleco’s net cash used in financing activities for the predecessor period January 1, 2016, through March 31, 2016, was $40.8 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 $81.2 million and $110.3 million during the three months ended March 31, 2017, and 2016, respectively. Net cash provided by operating activities decreased$29.1 million primarily due to:

• higher payments for fuel inventory of $23.4 million primarily due to higher lignite purchases and higher petroleum coke purchases and

• lower collections from customers of $3.4 million due to Merger credits issued in 2016.

Net Investing Cash Flow

Net cash used in investing activities was $36.8 million and $31.2 million during the three months ended March 31, 2017, and 2016, respectively. Net cash used in investing activities increased $5.6 million primarily due to higher additions to property, plant, and equipment of $11.3 million, partially offset by higher transfers of cash from restricted accounts of $4.7 million.

Net Financing Cash Flow

Net cash used in financing activities was $44.7 million and $34.2 million during the three months ended March 31, 2017, and 2016, respectively. Net cash used in financing activities increased $10.5 million primarily due to higher distributions to Cleco Holdings of $10.0 million.

Contractual Obligations

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

For more information regarding Cleco’s Contractual Obligations, see Part II, Item 7, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Contractual Obligations” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 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 them to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees. For more information about off-balance sheet commitments and 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.”

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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.

In February 2012, the EPA finalized the MATS ruling that requires affected EGUs to meet strict emission limits on new and existing coal- and liquid oil-fired EGUs for mercury, acid gases, and non-mercury metallic pollutants. Cleco Power units impacted by the rule included Rodemacher Unit 2, Madison Unit 3, and Dolet Hills Power Station. MATS controls equipment was installed and Cleco Power’s three EGUs affected by the MATS rule were compliant by the April 16, 2015, deadline. In February 2016, the LPSC approved Cleco Power’s request for authorization to recover the revenue requirements associated with the MATS equipment. As of March 31, 2017, Cleco Power had spent $106.2 million on the project. Cleco Power’s final project cost is expected to be $108.0 million, with the remaining costs being related to post-construction refinements. On March 31, 2016, the Sierra Club filed a petition for judicial review in the 19th Judicial District Court, State of Louisiana, requesting that the LPSC’s approval of MATS be vacated. Briefs have been filed, but the court has not set a date for the oral argument. Cleco believes the LPSC’s approval was neither arbitrary nor capricious and, as such, believes the Sierra Club’s request to be without merit. In June 2015, the U.S. Supreme Court remanded the MATS rule to the D.C. Circuit Court of Appeals. The Supreme Court held that the EPA had not demonstrated that the promulgation of the MATS rule was “appropriate and necessary” due to the EPA’s failure to consider costs. 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 the rule. On April 15, 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.

On March 28, 2017, the President signed a broad executive order. Among other measures, the order directs the EPA to review the CPP, the proposed Federal Implementation Plan for the CPP, and the greenhouse gas new source performance standards (GHG NSPS). It also gives 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.

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 will be performed at least every other year. On February 3, 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 this 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 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. On February 3, 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 this audit was $81.2 million. On December 1, 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. Cleco Power began incurring additional environmental compliance expenses in the second quarter of 2015 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 “ — Environmental Matters.”

On April 8, 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

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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. On April 8, 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. On October 4, 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 anticipates the completion of this agreement in the second half of 2017. 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.

System Support Resource (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. Cleco Power is unable to determine when a binding FERC order will be issued. MISO will allocate 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 will be performed by MISO to determine if an SSR Agreement will be needed after March 31, 2018. At the end of the SSR, Cleco will have the option to rescind the Attachment Y requesting retirement of Teche Unit 3 and would be obligated to refund recoverable capital expenditures plus interest. Management does not expect to be obligated 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 the fourth quarter of 2018. 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 recovering approximately $3.3 million annually of estimated costs for the program though an approved rate tariff.

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. On March 1, 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 is expected to be filed in 2018.

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. 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, is for the period November 2013 through February 2015. On September 29, 2016, FERC issued a Final Order in response to the first complaint establishing a 10.32% ROE.

In February 2015, the second ROE complaint was filed 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 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, in 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 March 31, 2017, Cleco Power had $1.9 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. 

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For more 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 proposed 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 Southwest Power Pool Regional Entity (SPP 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.

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 March 31, 2017, and December 31, 2016, Cleco Power had $5.7 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.

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. On April 7, 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 August 2020. 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.

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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 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.”

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 8, 2016, taking into consideration the anticipated completion of the Merger, S&P and Moody’s downgraded Cleco Holdings’ credit ratings to BBB- (stable) and Baa3 (stable), respectively. On April 8, 2016, taking into consideration the anticipated completion of the Merger, S&P and Moody’s credit ratings were maintained at Cleco Power at BBB+ (stable) and A3 (stable), respectively. On April 7, 2017, Moody’s updated its credit ratings by maintaining Cleco Holdings at Baa3 (stable) and Cleco Power at A3 (stable). 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.

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At March 31, 2017, Cleco had $0.5 million short-term variable rate debt outstanding at a rate of 2.73%. This debt was repaid on April 3, 2017.

Cleco had no long-term variable-rate debt under Cleco Holdings’ $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 March 31, 2017, Cleco 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 March 31, 2017, the all-in rate was 2.455%.

Each 1% increase in the interest rate applicable to such debt would result in a decrease in Cleco’s pretax earnings of $3.0 million.

For a discussion on the long-term variable-rate debt related to Cleco Power, please refer to “— Cleco Power.”

Commodity Price Risks

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

Cleco Power provides fuel for generation and purchases power to meet the power demands of customers. Cleco Power may enter into positions to mitigate the volatility in customer fuel costs, as encouraged by various LPSC orders. These positions would be marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of the accumulated deferred fuel asset or liability and a component of the energy risk management assets or liabilities. When these positions close, actual gains or losses would be included in the FAC and reflected in customers’ bills as a component of the fuel charge. There were no open natural gas positions at March 31, 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 is currently scheduled to be submitted to the LPSC by June 30, 2017.

Cleco Power purchases the majority of its FTRs in annual auctions facilitated by MISO during the second quarter of each

year and may also purchase additional FTRs in monthly auctions facilitated by MISO. 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 initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period 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 March 31, 2017, Cleco Power’s Condensed Consolidated Balance Sheets reflected open FTR positions of $5.0 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 March 31, 2017, Cleco Power had no short-term variable-rate debt or long-term variable-rate debt.

At March 31, 2017, Cleco Power had no borrowings 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 March 31, 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 March 31, 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 HOLDINGS

For information on legal proceedings affecting Cleco Holdings, 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 5.OTHER INFORMATION

The foregoing descriptions of the LTIP and STIP do not purport to be complete and are subject to, and qualified in their entirety by, the full text of the LTIP and STIP, respectively, which are filed as Exhibit 10.3 and Exhibit 10.6, respectively, to this Quarterly Report on Form 10-Q and are incorporated herein by reference.

LTIP

On May 10, 2017, the Board of Managers of Cleco Holdings adopted the Cleco Corporate Holdings LLC 2017 LTIP to be effective as of January 1, 2017. The LTIP is designed to grow the value of Cleco Holdings’ business and encourage results-oriented actions on the part of its participants. The primary objective of the LTIP is to provide financial motivation for key officers, executives, and key employees to achieve or exceed established performance goals that support Cleco Holdings’

long-term business strategies. The LTIP is paid out according to performance objectives based on EBITDA and consolidated ROE for the applicable performance cycles with a payout range of 50% to 200% of target based on actual performance.

STIP

On May 10, 2017, the Board of Managers of Cleco Holdings adopted the Cleco Corporate Holdings LLC STIP to be effective as of January 1, 2017. The purposes of the STIP are to: (a) provide annual cash incentives to officers and employees of the Company; (b) attract and retain officers and employees; and (c) further align the interests of employees and officers of the Company with the interests of its owners. The STIP is paid out according to financial performance of the Company based on EBITDA, operational performance of the Company, and individual performance.

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ITEM 6.   EXHIBITS
CLECO
10.1	Separation Agreement, dated effective March 23, 2017, by and among Cleco Group LLC, Cleco Corporate Holdings LLC, and Cleco Power LLC and Darren J. Olagues (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed March 28, 2017)
10.2	Interim Executive Employment Agreement, effective February 8, 2017, by and between Peggy Scott and Cleco Group LLC (incorporated by reference to Exhibit 10(k) to the Annual Report on Form 10-K for the year ended December 31, 2016, filed on February 22, 2017)
10.3	2017 Long-Term Incentive Compensation Plan, effective as of January 1, 2017
10.4	Form of Notice and Acceptance of Incentive Award under Cleco Corporate Holdings LLC 2017 Long-Term Incentive Compensation Plan - 2017 Two-Year Performance Cycle
10.5	Form of Notice and Acceptance of Incentive Award under Cleco Corporate Holdings LLC 2017 Long-Term Incentive Compensation Plan - 2017 Three-Year Performance Cycle
10.6	2017 Short-Term Incentive Plan, effective as of January 1, 2017
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
10.1	Separation Agreement, dated effective March 23, 2017, by and among Cleco Group LLC, Cleco Corporate Holdings LLC, and Cleco Power LLC and Darren J. Olagues (incorporated by reference to Exhibit 10.1 to the Current Report on Form 8-K filed March 28, 2017)
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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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: May 11, 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: May 11, 2017

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EX-10.3

Exhibit 10.3

CLECO CORPORATE HOLDINGS LLC

2017 LONG-TERM INCENTIVE COMPENSATION PLAN

CLECO CORPORATE HOLDINGS LLC

2017 LONG TERM INCENTIVE COMPENSATION PLAN

TABLE OF CONTENTS

Page

ARTICLE I. PURPOSE			1
ARTICLE II. DEFINITIONS			1
	2.1	Affiliate	1
	2.2	Beneficiary	1
	2.3	Board or Board of Managers	1
	2.4	Cause	1
	2.5	Change in Control	2
	2.6	Change in Control Period	3
	2.7	Code	3
	2.8	Committee	3
	2.9	Company	3
	2.10	Disability	3
	2.11	Employee	3
	2.12	Employer	3
	2.13	Exchange Act	3
	2.14	Good Reason	3
	2.15	Incentive	4
	2.16	Involuntary or Involuntarily	4
	2.17	Participant	4
	2.18	Performance Cycle	4
	2.19	Performance Objectives	4
	2.20	Plan	4
	2.21	Pro-Rata	5
	2.22	Retirement or Retire	5
	2.23	Separation Date or Separation from Service	5
	2.24	Specified Employee	5
	2.25	Year of Service	5
ARTICLE III. ADOPTION			5
	3.1	Adoption and Effective Date	5
	3.2	Duration	5
ARTICLE IV. PARTICIPATION			6
	4.1	Eligibility	6
	4.2	No Continued Employment	6
ARTICLE V. ADMINISTRATION OF PLAN			6
	5.1	Composition of/Actions by the Committee	6
	5.2	Power and Authority	6
ARTICLE VI. PERFORMANCE INCENTIVES			7
	6.1	Performance Objectives for a Performance Cycle	7
	6.2	Vesting	7
	6.3	Time and Form of Payment	10
	6.4	Tax Withholding	10

i

ARTICLE VII. MISCELLANEOUS			10
	7.1	Amendment and Termination	10
	7.2	Transferability of Incentives	10
	7.3	Agreements	10
	7.4	Governing Law	10
	7.5	Other Benefits	10
	7.6	Recovery Policy	11
	7.7	Compliance with Code Section 409A	11
Exhibit A 2017-2018 Performance Cycle			12
Exhibit B 2017-2019 Performance Cycle			13

ii

CLECO CORPORATE HOLDINGS LLC

2017 LONG-TERM INCENTIVE COMPENSATION PLAN

Cleco Corporate Holdings LLC (the "Company"), hereby establishes the 2017 Long-Term Incentive Compensation Plan (the "Plan") for the benefit of eligible employees.

ARTICLE I.

PURPOSE

This Plan is established effective as of January 1, 2017. It is designed to grow the value of the Company’s business and encourage results-oriented actions on the part of Participants. The primary objective of the Plan is to provide financial motivation for key officers, executives, and key employees to achieve or exceed established performance goals that support the Company’s long-term business strategies.

ARTICLE II.

DEFINITIONS

2.1Affiliate means any corporation or other form of entity of which the Company, owns, from time to time, directly or indirectly, at least 50% of the total combined voting power of all classes of stock or other equity interests.

2.2Beneficiary means the Participant's surviving spouse or estate, as determined in the discretion of the Committee.

2.3Board or Board of Managers means the Board of Managers of the Company.

2.4Cause, unless otherwise specified in an employment or similar agreement between a Participant and the Company, means that a Participant has:

(a)Committed an intentional act of fraud, embezzlement or theft in the course of employment or otherwise engaged in any intentional misconduct which is materially injurious to the financial condition or business reputation of the Company or its Affiliates;

(b)Committed intentional damage to the property of the Company and its Affiliates or committed intentional wrongful disclosure of proprietary information or confidential information, which is materially injurious to the financial condition or business reputation of the Company or its Affiliates;

(c)Been convicted with no further possibility of appeal, or entered a guilty or nolo contendere plea, for a felony or a crime involving moral turpitude;

(d)Willfully and substantially refused to perform the essential duties of his or her position after written notice from the Company;

2017 Long-Term Incentive Compensation Plan Page 1

(e)Intentionally, recklessly or negligently violated any material provision of the Company's code of conduct or equivalent code of policy that is applicable to the Participant;

(f)Intentionally, recklessly or negligently acted or failed to act in a manner which materially compromises his or her ability to perform the essential duties of his or her position;

(g)Intentionally, recklessly or negligently violated any material provision of the Sarbanes-Oxley Act of 2002 or any of the rules adopted by the Securities and Exchange Commission implementing any such provision; or

(h)Failed to fully cooperate to the extent requested by the Company or an Affiliate with investigations by government or independent agencies involving the Company or an Affiliate.

No act or failure to act on the part of a Participant will be deemed intentional if it was due primarily to an error in judgment or negligence, but will be deemed intentional only if done or omitted to be done by a Participant not in good faith and without reasonable belief that his or her action or omission was in the best interest of the Company or an Affiliate.

2.5Change in Control means and shall be deemed to occur upon the consummation of:

(a)Any "person" (as such term is used in Sections 13(d) and 14(d) of the Exchange Act), other than the Company or an Affiliate or any "person" who on the effective date of this Plan is a director, officer, or is the "beneficial owner" (as determined in Rule 13d-3 promulgated under the Exchange Act) of 20% or more of the combined voting power of outstanding securities of the Company or an employee stock ownership plan (within the meaning of Code Section 4975(e)(7)) sponsored by the Company or an Affiliate, is or becomes the "beneficial owner" (as determined in Rule 13d-3 promulgated under the Exchange Act) of 80% or more of the combined voting power of the outstanding securities of the Company;

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

(c)The Company sells, leases, or otherwise disposes of, in one transaction or in a series of related transactions, all or substantially all of its assets;

(d)The owners of the Company approve a plan of dissolution or liquidation; or

2017 Long-Term Incentive Compensation Plan Page 2

(e)All or substantially all of the assets or the issued and outstanding membership interests of Cleco Power LLC is sold, leased or otherwise disposed of in one or a series of related transactions to a person, other than the Company or an Affiliate.

The Board of Managers shall determine whether a Change in Control has occurred hereunder.

2.6Change in Control Period means the 60-day period preceding and the 24-month period following the consummation of a Change in Control.

2.7Code means the Internal Revenue Code of 1986, as amended.

2.8Committee means the Leadership Development & Compensation Committee appointed according to Section 5.1 to administer this Plan.

2.9Companymeans Cleco Corporate Holdings LLC.

2.10Disability means that a Participant, by reason of a medically determinable physical or mental impairment that can be expected to result in death or last for a continuous period of not less than 12 months, (a) has been receiving income replacement benefits for a period of not less than three months under a separate long-term disability plan or policy maintained by the Company or an Affiliate, or (b) is unable to engage in any substantial gainful employment.

2.11Employee means a regular, common law employee of the Company and/or an Affiliate determined in accordance with the Employer's standard personnel policies and practices, but excluding individuals who the Employer classifies as leased or otherwise employed by a third party, independent contractors or intermittent or temporary employees, even if any such classification is modified by audit, administrative proceeding, litigation or otherwise.

2.12Employer means the Company and its Affiliates, as applicable.

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

2.14Good Reason means that:

(a)a Participant’s base compensation in effect immediately before the commencement of a Change in Control Period is materially reduced, or there is a material reduction or termination of such Participant’s rights to any employee benefit in effect immediately prior to such period;

(b)a Participant’s authority, duties or responsibilities are materially reduced from those in effect immediately before the commencement of a Change in Control Period, or such Participant has reasonably determined that, as a result of a change in circumstances that materially affects his or her employment with the Company, he or she is unable to exercise the authority, power, duties and responsibilities assigned to him or her immediately before the commencement of such period; or

2017 Long-Term Incentive Compensation Plan Page 3

(c)a Participant is required to transfer to an office or business location that is more than 60 miles from the primary location to which he or she was assigned prior to the commencement of a Change in Control Period.

No event or condition shall constitute Good Reason hereunder unless:

(1)a Participant provides to the Committee written notice of his or her objection to such event not later than 60 days after such Participant first learns, or should have learned, of such event;

(2)such event is not corrected by the Company promptly after receipt of such notice, but in no event more than 30 days after receipt thereof; and

(3)such Participant Separates from Service not more than 15 days following the expiration of the 30-day period described in clause (2) hereof.

One or more members of the Committee, as constituted immediately before the commencement of a Change in Control Period, shall determine whether any Separation from Service is on account of Good Reason as defined herein.

2.15Incentive means a bonus payable to a Participant based on the portion the Committee assigns to the Participant of the Payout, if any, based on actual results achieved with respect to Performance Targets for a Performance Cycle.

2.16Involuntary or Involuntarily means a Separation from Service because of the independent exercise of the unilateral authority of the Employer to terminate the Participant’s services, other than because of the Participant’s implicit or explicit request, if the Participant was willing and able to continue performing services.

2.17Participant means an Employee who is granted or awarded an Incentive under this Plan as provided in Section 4.1.

2.18Performance Cycle means the period the Committee designates during which Performance Objectives the Committee designates are obtained.

2.19Performance Objectives means performance criteria the Committee designates to be achieved during a Performance Cycle the Committee designates. Such objectives may relate to the business and affairs of the Company, an Affiliate, a division, department, unit or profit center of the Company or an Affiliate. For example, the Committee may designate threshold, target and maximum percentages with respect to one or more Performance Objectives as well as the weighting to be applied to the actual results achieved with respect to various Performance Objectives. The Committee and the Board of Managers shall have discretion to assess actual results of the Performance Objectives against targets at the completion of each Performance Cycle for purposes of determining the payout to Participants.

2.20Plan means this 2017 Long-Term Incentive Compensation Plan, as may be amended from time to time.

2017 Long-Term Incentive Compensation Plan Page 4

2.21Pro-Rata is defined in Section 6.2(f).

2.22Retirement or Retire means the Committee determined that the Participant Separated from Service from the Employer other than for Cause (regardless of whether the Separation from Service was Involuntary or voluntary at the Company's request) and that the Participant met one of the following conditions:

(a)the Participant Separated from Service after reaching age 55 with at least 10 Years of Service;

(b)the Participant Separated from Service after reaching age 60 with at least 5 Years of Service; or

(c)the Participant Separated from Service after reaching age 65.

2.23Separation Date or Separation from Service means the later of the date on which (a) a Participant's employment with the Company and its Affiliates ceases, or (b) the Company and such Participant reasonably anticipate that he or she will perform no further services for the Company and its Affiliates, whether as a common law employee or independent contractor. Notwithstanding the foregoing, a Participant may be deemed to have Separated from Service if he or she continues to provide services to the Company or an Affiliate, whether as an employee or an independent contractor, provided such continuing services are not more than 20% of the average level of services performed by such Participant during the immediately preceding 36-month period.

2.24Specified Employee shall be determined in accordance with Code Section 409A and shall generally mean that a Participant is a "key employee" of the Company or an Affiliate, within the meaning of Code Section 416(i)(1)(A)(i), (ii) or (iii), but determined without regard to paragraph (i)(5) thereof, as of his or her Separation Date. A Participant who satisfies such requirement as of a December 31st shall be considered a Specified Employee hereunder during the 12-month period commencing on the immediately following April 1st.

2.25Year of Service has the meaning given to that term by the separate defined benefit plan maintained by the Employer, without regard to whether the individual in question is eligible to participate in that plan.

ARTICLE III.

ADOPTION

3.1Adoption and Effective Date. This Plan shall be effective as of January 1, 2017 (the "Effective Date").

3.2Duration. This Plan shall commence on its Effective Date and shall remain in effect until all Incentives have been satisfied by cash payments or have been expired, terminated or forfeited.

2017 Long-Term Incentive Compensation Plan Page 5

ARTICLE IV.

PARTICIPATION

4.1Eligibility. Employees shall be eligible to receive Incentives under this Plan, when designated by the Committee. Employees may be designated for participation hereunder individually or by groups or categories, in the discretion of the Committee.

4.2No Continued Employment. No Participant shall have any right to continue in the employ of the Company or an Affiliate for any period of time or any right to continue his or her present or any other rate of compensation on account of the grant or award of an Incentive or other form of payment hereunder.

ARTICLE V.

ADMINISTRATION OF PLAN

5.1Composition of/Actions by the Committee. This Plan shall be administered by a Leadership Development & Compensation Committee (the "Committee") that is appointed by the Board of Managers and that shall consist of not less than two persons. All powers granted to the Committee hereunder are subject to the approval and direction of the Board. The Committee, in its discretion, may delegate to one or more executive officers of the Company the authority to grant or award Incentives hereunder, except that the authority to make grants and awards to the Company's named executive officers shall not be subject to delegation hereunder. Any grant or award made pursuant to such delegation shall be subject to subsequent ratification by the Board. Notwithstanding the foregoing, the Board of Managers may act in lieu of the Committee hereunder.

5.2Power and Authority. The Committee shall have the discretionary power and authority to (a) designate Participants hereunder, (b) grant or award Incentives under the Plan, including the determination of the terms and conditions thereof, (c) construe and interpret the provisions of the Plan and any form or agreement related thereto, (d) establish and adopt rules, regulations, and procedures relating to the Plan and the grant or award of Incentives hereunder, including, without limitation, procedures for the crediting of periods of employment with an Affiliate and/or during any period of part-time employment, (e) interpret, apply and construe such rules, regulations and procedures, and (f) make any other determination which it believes necessary or advisable for the proper administration of the Plan.

Decisions, interpretations and actions of the Committee concerning matters related to the Plan shall be final and conclusive on the Company, its Affiliates and Participants and their beneficiaries or heirs. The Committee may make determinations selectively among Participants who receive or are eligible to receive Incentives hereunder, whether or not such Participants are similarly situated.

2017 Long-Term Incentive Compensation Plan Page 6

ARTICLE VI.

PERFORMANCE INCENTIVES

6.1Performance Objectives for a Performance Cycle.

(a)In General. Each year the Committee, in its discretion, may establish a Performance Cycle and Performance Objectives for that Performance Cycle.

(b)Subsequent Adjustments.

(1)Performance Objectives. Once established, Performance Objectives may be changed, adjusted or amended during the Performance Cycle, in the discretion of the Committee, on account of a change in circumstances. For example, at any time before the final determination of awards, the Committee may equitably adjust the Performance Objectives and payout amounts to reflect:

(i)a change in entity capitalization, or an entity level transaction (such as a merger, consolidation, separation, reorganization or partial or complete liquidation),

(ii)the occurrence of any extraordinary event or unforeseen occurrence, or

(iii)any change in applicable accounting rules or principles, any change in the Company’s or an Affiliate’s accounting method, or any change in applicable law.

(2)Unsatisfactory Job Performance. The Committee shall have the discretion to adjust any Participant’s Incentive for unsatisfactory job performance.

(3)Adjustments are not Amendments. Adjustments to Performance Objectives or for unsatisfactory performance shall not be considered an amendment to the Plan requiring consent as described in section 7.1.

6.2Vesting.

(a)In General. Incentives for each Performance Cycle vest separately. Except as provided in subsections 6.2(c), (d), and (e), a Participant shall become vested in 100% of his Incentive with respect to a Performance Cycle if the Participant remains employed by the Employer until the last day of the Performance Cycle. For example, a Participant will vest in his Incentive for a Performance Cycle from January 1, 2017 to December 31, 2019 if he remains employed by the Employer until December 31, 2019.

(b)Voluntary Termination or Termination for Cause. Except as provided in subsections 6.2(c), (d), and (e), a Participant forfeits any unvested Incentives if the Participant Separates from Service before the end of a Performance Cycle or it the

2017 Long-Term Incentive Compensation Plan Page 7

Participant Separates from Service for Cause (regardless of whether the Separation from Service was Involuntary or voluntary at the Company's request).

(c)Involuntary Termination, Disability, and Death. A Participant will become vested in a Pro-Rata portion of his Incentive for a Performance Cycle if during a Performance Cycle:

(1)Involuntary. The Participant Separates from Service with the Employer Involuntarily, other than for Cause, the Committee in its discretion approves the Participant’s vesting, and the Participant satisfies the requirements of section 6.2(g);

(2)Death. The Participant dies; or

(3)Disability. The Participant ceases to be actively employed by the Employer because of the Participant's Disability and the Participant satisfies the requirements of section 6.2(g).

(d)Retirement. A Participant who satisfies the requirements of section 6.2(g) and who Separates from Service with the Employer because of Retirement shall be vested in any outstanding Incentives as follows:

(1)Age 55 with 10 Years of Service. If the Participant Retires after reaching age 55 and has at least 10 Years of Service with the Employer, the Participant will become vested in a Pro-Rata portion of his outstanding Incentives.

(2)Age 60 with 5 Years of Service or Age 65. If the Participant Retires after reaching age 60 with at least 5 Years of Service with the Employer or after the Participant reaches age 65:

(i)Incentives Granted Before Year of Retirement. The Participant will become vested in 100% of his outstanding Incentives granted for years before the year in which the Participant Retires under this paragraph.

(ii)Incentives Granted for Year of Retirement. The Participant will become vested in a Pro-Rata portion of Incentives granted for the year of the Participant's Retirement under this paragraph. Thus, a Participant will become 100% vested in an Incentive granted for the year the Participant Retires under this Paragraph if the Participant remains employed until the end of that calendar year.

(3)Grandfathered SERP Benefit. If the Participant has a grandfathered Supplemental Executive Retirement Plan (SERP) benefit when he Retires, the Participant will become vested in a Pro-Rata portion of his outstanding Incentives regardless of his age and Years of Service.

2017 Long-Term Incentive Compensation Plan Page 8

(e)Change in Control. On the effective date of a Change in Control, if the Participant satisfies the requirements of section 6.2(g), the Board of Managers has discretion to keep the Plan in place and adjust performance goals as appropriate under section 6.1(b)(1) or terminate the Plan.

(1)Involuntary Termination without Cause or Separation from Service for Good Reason. If the Board keeps the Plan in place and a Participant Involuntarily Separates from Service without Cause or Separates from Service for Good Reason during the Change in Control Period, the Participant will become vested in 100% of his outstanding Incentives for all Performance Cycles. Such Incentives shall be computed assuming that the target Performance Objectives for each Performance Cycle had been achieved and shall be paid within 60 days of the Participant's Separation from Service.

(2)Plan Termination. If the Board terminates the Plan, all Participants will become vested in a Pro-Rata portion of their Incentives for all outstanding Performance Cycles. Such Incentives shall be computed assuming that the target Performance Objectives for each Performance Cycle had been achieved and shall be paid within 60 days of the date the Plan is terminated.

(f)Pro-Rata. Pro-Rata vesting of an Incentive for a Performance Cycle is based on the number of complete months the Participant was actively employed by the Employer during that Performance Cycle or, in the case of Plan termination, based on the number of full months of each Performance Cycle that were completed on the Plan termination date. For example, if a Participant died on July 15, 2018, during a 24-month Performance Cycle from January 1, 2017 to December 31, 2018, the Participant will become vested in 75% of his Incentive for that Performance Cycle (18 completed months of employment divided by 24). Pro-Rata vesting shall be based on actual performance at the end of each Performance Cycle and paid after the end of the Performance Cycle as provided in Section 6.3, except as provided in section 6.2(e) in connection with a Change in Control.

(g)Waiver, Release and Covenants Agreement. Vesting under Section 6.2(c), (d), or (e) will not be available unless the Participant executes and timely delivers to the Company such agreement or agreements as the Company, in its sole discretion, shall deem necessary or appropriate to protect its business and economic value, including the business and economic value of its Affiliates, such agreement or agreements to provide for any one or more of the following: a waiver and release in favor of the Company and its Affiliates; covenants protecting confidential information; covenants prohibiting competition; covenants prohibiting the solicitation of customers and employees; and prohibitions on disparagement by the Participant and the Company. Such Agreement shall be substantially in the form attached to the Cleco Corporate Holdings LLC Executive Severance Plan, as it may be modified in the discretion of the Committee from time to time. To be timely, the Participant must execute and return such agreements to the Company within the time both specified in the agreement and so the Company can make payment to the Participant on the dates provided above and within

2017 Long-Term Incentive Compensation Plan Page 9

the time provided by Treasury Regulation Section 1.409A-1(b)(4) or to otherwise comply with Code Section 409A.

6.3Time and Form of Payment. A Participant's vested Incentive for a Performance Cycle will be paid to the Participant or, in the case of death, to his Beneficiary as soon as administratively feasible following the end of the Performance Period, but not later than the 15th day of the third month of the calendar year following the end of such Performance Cycle.

6.4Tax Withholding. Payments with respect Incentives shall be subject to payroll tax withholding according to applicable law.

ARTICLE VII.

MISCELLANEOUS

7.1Amendment and Termination. The Board of Managers may amend or terminate this Plan at any time; any such action may be taken without the approval of the Company's owners, but only to the extent that owner approval is not required under applicable Federal or state law, regulation.

The Committee or the Board of Managers, as the case may be, shall possess the authority to amend the terms of an Incentive granted or awarded hereunder; provided, however, that no such amendment shall materially impair any such Incentive without the consent of each affected Participant.

7.2Transferability of Incentives. Except as expressly provided in this Section 7.2, no Incentive granted hereunder shall be transferred, pledged, assigned, hypothecated, alienated or otherwise encumbered or sold by the holder thereof, whether by operation of law or otherwise, and whether voluntarily or involuntarily (except in the event of the holder's death by will or the laws of descent and distribution) and neither the Committee nor the Company shall be required to recognize any attempted assignment of such rights by any Participant.

7.3Agreements. The terms of each Incentive granted or awarded hereunder shall be evidenced by a separate agreement between each Participant and the Committee setting forth the terms and conditions applicable to such Incentive; such agreement shall be made in writing or by such electronic means as the Committee deems appropriate.

7.4Governing Law. Except to the extent preempted by federal law, the Plan and any Incentive granted under the Plan shall be governed by the laws of the State of Louisiana, without regard to the conflicts of law provisions thereof.

7.5Other Benefits. Incentives granted to a Participant under the terms of the Plan shall not impair or otherwise reduce such Participant's compensation, life insurance or other benefits provided by the Company or its Affiliates; provided, however, that the value of Incentives shall not be treated as compensation for purposes of computing the value or amount of any such benefit.

2017 Long-Term Incentive Compensation Plan Page 10

7.6Recovery Policy. If the Company or an Affiliate is required to restate its financial statements or other financial results, the Committee may take such action as it deems necessary or appropriate, to the extent consistent with applicable law, to cause the reduction, forfeiture or recovery of any payment with respect to an Incentive, provided that:

(a)The amount of such payment was predicated, directly or indirectly, on the achievement of financial statement measures or results that were subject to material restatement;

(b)The affected Participant was grossly negligent or engaged in intentional misconduct or an intentional act or omission, as determined by the Committee in connection with the restatement; and

(c)The amount of any such payments would have been lesser if it had been based upon the restated results.

7.7Compliance with Code Section 409A. If any Incentive is determined to be subject to Code Section 409A, this Plan and any agreement issued or procedure adopted in connection therewith is intended to comply and to be interpreted and construed in accordance with the provisions of Code Section 409A. With respect to any Code Section 409A governed Incentive granted or awarded hereunder and notwithstanding any provision of this Plan or the terms of any such Incentive to the contrary, the Committee (or its designee) shall exercise any discretion afforded hereunder only to the extent such discretion may be exercised in accordance with the provisions of Code Section 409A.

If a Participant is a Specified Employee as of his or her Separation Date, any cash payment to be made on account of such Participant's Separation from Service, including Retirement, shall be postponed until the first business day of the seventh calendar month following his or her Separation Date. The Company shall make such payment at the time provided herein without liability for interest or other loss of investment opportunity.

This Plan was approved by the Board Managers of Cleco Corporate Holdings LLC on the date indicated below to be effective as of January 1, 2017.

Cleco Corporate Holdings LLC

By:      /s/ Chris Leslie                                       

Print Name:      Chris Leslie                               

Title:  Chairman, Leadership Development &   

Compensation Committee

Date       May 9, 2017                                         

Exhibits:

Exhibit A - 2017-2018 Performance Cycle

Exhibit B - 2017-2019 Performance Cycle

2017 Long-Term Incentive Compensation Plan Page 11

CLECO CORPORATE HOLDINGS LLC

2017 LONG-TERM INCENTIVE COMPENSATION PLAN

Exhibit A

2017-2018 Performance Cycle

Target Incentive Percentages: Determined at the beginning of the Performance Cycle

Performance Cycle: January 1, 2017 - December 31, 2018

Performance Objectives: 50% on the 2-year cumulative consolidated EBITDA as projected in the business plan, adjusted for pension, SERP and other approved exclusions

50% on 2-year average consolidated ROE, including wholesale, as projected in the business plan

Payout Range: 50% to 200% based on actual performance of EBITDA and ROE

Final Award: Payout determined on each measure and then weighted 50%-50%

A	B	C	D	E
Performance Objectives	Weight	Threshold (50% Payout)	Target (100% Payout)(1)	Maximum (200% Payout)
Return on Equity	50%	8.303%	9.225%	10.148%
Cumulative EBITDA	50%	$838.08M	$931.20M	$1,024.32M

⁽¹⁾ Results between threshold and target and between target and maximum will be interpolated on a straight-line basis.

2017 Long-Term Incentive Compensation Plan Page 12

CLECO CORPORATE HOLDINGS LLC

2017 LONG-TERM INCENTIVE COMPENSATION PLAN

Exhibit B

2017-2019 Performance Cycle

Target Incentive Percentages: Determined at the beginning of the Performance Cycle

Performance Cycle: January 1, 2017 - December 31, 2019

Performance Objectives: 50% on the 3-year cumulative consolidated EBITDA as projected in the business plan, adjusted for pension, SERP and other approved exclusions

50% on 3-year average consolidated ROE, including wholesale, as projected in the business plan

Payout Range: 50% to 200% based on actual performance of EBITDA and ROE

Final Award: Payout determined on each measure and then weighted 50%-50%

A	B	C	D	E
Performance Objectives	Weight	Threshold (50% Payout)	Target (100% Payout)(1)	Maximum (200% Payout)
Return on Equity	50%	8.283%	9.203%	10.123%
Cumulative EBITDA	50%	$1,280.97M	$1,423.30M	$1,565.63M

⁽¹⁾ Results between threshold and target and between target and maximum will be interpolated on a straight-line basis.

2017 Long-Term Incentive Compensation Plan Page 13

EX-10.4

Exhibit 10.4

CLECO CORPORATE HOLDINGS LLC

2030 Donahue Ferry Road

Pineville, LA 71360

May __, 2017

«Name»

«Location»

Re:Incentive Award - 2017 Two-Year Performance Cycle

Dear «Nickname»:

The Leadership Development & Compensation Committee (the “Committee”) of the Board of Managers of Cleco Corporate Holdings LLC (the “Company”), which is appointed to administer the Cleco Corporate Holdings LLC 2017 Long-Term Incentive Compensation Plan (“LTIP”) has awarded you an “Incentive” subject to the terms and conditions set forth herein. Your target Incentive to which the payout percentage for the 2017 Two-Year Performance Cycle will be applied is $_____.

1.Incentive. The amount payable with respect to your Incentive is based on the attainment of Performance Objectives during the 2017 Two-Year Performance Cycle (defined below).

2.Performance Objectives, Vesting, and Delivery. A summary of the Performance Objectives and a payment matrix applicable to your Incentive are attached as Exhibit A. Attainment of the Performance Objectives, whether in whole or in part, shall be during the period beginning January 1, 2017, and ending December 31, 2018 (the “2017 Two-Year Performance Cycle”).

As soon as practicable after the end of the 2017 Two-Year Performance Cycle, the Committee will notify you of the payment, if any, you will receive with respect to the Incentive. Payment will be subject to applicable payroll tax withholdings.

3.Separation from Service. If you Separate from Service with the Company and its Affiliates before the end of the 2017 Two-Year Performance Cycle, your Incentive will be forfeited, except as may be expressly provided in the LTIP with respect to your Retirement, Involuntary Separation from Service without Cause, death, Disability, or termination under a Change in Control.

If you are entitled to receive an Incentive in connection with your Separation from Service, payment will be conditioned upon your timely execution and delivery to the Company of a Waiver, Release and Covenants Agreement in the form prescribed by the Company.

4.Recovery Policy. Since the final amount of your Incentive may be contingent on the financial performance of the Company, your Incentive is subject to the Company’s recovery policy. If the Company or an Affiliate is required to restate its financial statements or other financial results, the Committee may take such action as it deems necessary or appropriate, to the extent consistent with applicable law, to cause the reduction, forfeiture orrecovery of any payment with respect to an Incentive, provided that:

(a)the amount of such payment was predicated, directly or indirectly, on the achievement of financial statement measures or results that were subject to material restatement;

«Name»

May __, 2017

Page 2

(b)the affected Participant engaged in intentional misconduct or an intentional act or omission, as determined by the Committee in connection with the restatement; and

(c)the amount of any such payments would have been lesser if it had been based upon the restated results.

5.No Assignment. Your Incentive is not subject in any manner to sale, transfer, pledge, assignment or other encumbrance or disposition, whether by operation of law or otherwise and whether voluntarily or involuntarily, except by will or the laws of descent and distribution.

6.Employment Rights. Neither this Incentive nor the terms of the LTIP shall be deemed to confer upon you any right to continue in the employ of the Company or any Affiliate or interfere, in any manner, with any right of the Company or any of its Affiliates to terminate your employment, whether with or without Cause, in its sole discretion.

7.Amendment. The Committee or the Board of Managers may amend the terms and conditions set forth herein, except that any such amendment may not materially impair your Incentive without your prior consent.

In addition to the terms of this letter, your Incentive is subject to terms and conditions set forth in the LTIP. If there is any conflict between this letter and the terms of the LTIP document, the LTIP document will govern. You may obtain a copy of the full LTIP document by contacting Carla Works at Carla.Works@cleco.com. Capitalized terms used in this letter have the meanings ascribed to them in the LTIP. Please indicate your consent to be bound by the foregoing terms and conditions by executing below and returning this letter to Carla Works at PVGO7 not later than May __, 2017.

Very truly yours,

CLECO CORPORATE HOLDINGS LLC

By:

Its: Chief Administrative Officer

ACKNOWLEDGED AND AGREED TO

THIS _____ DAY OF ______________, 2017

__________________________________

«Name»

«Name»

May __, 2017

Page 3

CLECO CORPORATE HOLDINGS LLC

2017 LONG-TERM INCENTIVE COMPENSATION PLAN

Exhibit A

2017-2018 Performance Cycle

The Cleco Corporate Holdings LLC 2017 Long-Term Incentive Compensation Plan (the “LTIP”) requires that the Leadership Development & Compensation Committee of the Board of Managers (the “Committee”) of Cleco Corporate Holdings LLC (the “Company”) establish performance measures for each Performance Cycle.

For the 2017 Two-Year Performance Cycle, the comparative performance measure approved is based on the Company's consolidated earnings before interest, taxes, depreciation, and amortization ("EBITDA") and consolidated return on equity ("ROE"), as follows:

Target Incentive Percentages: Determined at the beginning of the Performance Cycle

Performance Cycle: January 1, 2017 - December 31, 2018

Performance Objectives: 50% on the 2-year cumulative consolidated EBITDA as projected in the business plan, adjusted for pension, SERP and other approved exclusions

50% on 2-year average consolidated ROE, including wholesale, as projected in the business plan

Payout Range: 50% to 200% based on actual performance of EBITDA and ROE

Final Award: Payout determined on each measure and then weighted 50%-50%

A	B	C	D	E
Performance Objectives	Weight	Threshold (50% Payout)	Target (100% Payout)(1)	Maximum (200% Payout)
Return on Equity	50%	8.303%	9.225%	10.148%
Cumulative EBITDA	50%	$838.08M	$931.20M	$1,024.32M

⁽¹⁾ Results between threshold and target and between target and maximum will be interpolated on a straight-line basis.

EX-10.5

Exhibit 10.5

CLECO CORPORATE HOLDINGS LLC

2030 Donahue Ferry Road

Pineville, LA 71360

May __, 2017

«Name»

«Location»

Re:Incentive Award - 2017 Three -Year Performance Cycle

Dear «Nickname»:

The Leadership Development & Compensation Committee (the “Committee”) of the Board of Managers of Cleco Corporate Holdings LLC (the “Company”), which is appointed to administer the Cleco Corporate Holdings LLC 2017 Long-Term Incentive Compensation Plan (“LTIP”) has awarded you an “Incentive” subject to the terms and conditions set forth herein. Your target Incentive to which the payout percentage for the 2017 Three-Year Performance Cycle will be applied is $_____.

1.Incentive. The amount payable with respect to your Incentive is based on the attainment of Performance Objectives during the 2017 Three-Year Performance Cycle (defined below).

2.Performance Objectives, Vesting, and Delivery. A summary of the Performance Objectives and a payment matrix applicable to your Incentive are attached as Exhibit A. Attainment of the Performance Objectives, whether in whole or in part, shall be during the period beginning January 1, 2017, and ending December 31, 2019 (the “2017 Three-Year Performance Cycle”).

As soon as practicable after the end of the 2017 Three-Year Performance Cycle, the Committee will notify you of the payment, if any, you will receive with respect to the Incentive. Payment will be subject to applicable payroll tax withholdings.

3.Separation from Service. If you Separate from Service with the Company and its Affiliates before the end of the 2017 Three-Year Performance Cycle, your Incentive will be forfeited, except as may be expressly provided in the LTIP with respect to your Retirement, Involuntary Separation from Service without Cause, death, Disability, or termination under a Change in Control.

If you are entitled to receive an Incentive in connection with your Separation from Service, payment will be conditioned upon your timely execution and delivery to the Company of a Waiver, Release and Covenants Agreement in the form prescribed by the Company.

4.Recovery Policy. Since the final amount of your Incentive may be contingent on the financial performance of the Company, your Incentive is subject to the Company’s recovery policy. If the Company or an Affiliate is required to restate its financial statements or other financial results, the Committee may take such action as it deems necessary or appropriate, to the extent consistent with applicable law, to cause the reduction, forfeiture orrecovery of any payment with respect to an Incentive, provided that:

(a)the amount of such payment was predicated, directly or indirectly, on the achievement of financial statement measures or results that were subject to material restatement;

«Name»

May __, 2017

Page 2

(b)the affected Participant engaged in intentional misconduct or an intentional act or omission, as determined by the Committee in connection with the restatement; and

(c)the amount of any such payments would have been lesser if it had been based upon the restated results.

5.No Assignment. Your Incentive is not subject in any manner to sale, transfer, pledge, assignment or other encumbrance or disposition, whether by operation of law or otherwise and whether voluntarily or involuntarily, except by will or the laws of descent and distribution.

6.Employment Rights. Neither this Incentive nor the terms of the LTIP shall be deemed to confer upon you any right to continue in the employ of the Company or any Affiliate or interfere, in any manner, with any right of the Company or any of its Affiliates to terminate your employment, whether with or without Cause, in its sole discretion.

7.Amendment. The Committee or the Board of Managers may amend the terms and conditions set forth herein, except that any such amendment may not materially impair your Incentive without your prior consent.

In addition to the terms of this letter, your Incentive is subject to terms and conditions set forth in the LTIP. If there is any conflict between this letter and the terms of the LTIP document, the LTIP document will govern. You may obtain a copy of the full LTIP document by contacting Carla Works at Carla.Works@cleco.com. Capitalized terms used in this letter have the meanings ascribed to them in the LTIP. Please indicate your consent to be bound by the foregoing terms and conditions by executing below and returning this letter to Carla Works at PVGO7 not later than May __, 2017.

Very truly yours,

CLECO CORPORATE HOLDINGS LLC

By:

Its: Chief Administrative Officer

ACKNOWLEDGED AND AGREED TO

THIS _____ DAY OF ______________, 2017

__________________________________

«Name»

«Name»

May __, 2017

Page 3

EXHIBIT A

CLECO CORPORATE HOLDINGS LLC

2017 LONG-TERM INCENTIVE COMPENSATION PLAN

PERFORMANCE OBJECTIVES

The Cleco Corporate Holdings LLC 2017 Long-Term Incentive Compensation Plan (the “LTIP”) requires that the Leadership Development & Compensation Committee of the Board of Managers (the “Committee”) of Cleco Corporate Holdings LLC (the “Company”) establish performance measures for each Performance Cycle.

For the 2017 Three-Year Performance Cycle, the comparative performance measure approved is based on the Company's consolidated earnings before interest, taxes, depreciation, and amortization ("EBITDA") and consolidated return on equity ("ROE"), as follows:

Target Incentive Percentages: Determined at the beginning of the Performance Cycle

Performance Cycle: January 1, 2017 to December 31, 2019

Performance Objectives: 50% on the 3-year cumulative consolidated EBITDA as projected in the business plan, adjusted for pension, SERP and other approved exclusions

50% on 3-year average consolidated ROE, including wholesale, as projected in the business plan

Payout Range: 50% to 200% based on actual performance of EBITDA and ROE

Final Award: Payout determined on each measure and then weighted 50%-50%

Performance Objectives	Weight	Threshold (50% Payout)	Target (100% Payout)(1)	Maximum (200% Payout)
Consolidated ROE	50%	8.283%	9.203%	10.123%
Consolidated EBITDA	50%	$1,280.97M	$1,423.30M	$1,565.63M

⁽¹⁾ Results between threshold and target and between target and maximum will be interpolated on a straight-line basis.

EX-10.6

Exhibit 10.6

CLECO CORPORATE HOLDINGS LLC

SHORT-TERM INCENTIVE PLAN

ARTICLE I. PURPOSE			1
ARTICLE II. DEFINITIONS			1
	2.1	Affiliate	1
	2.2	Award	1
	2.3	Board	1
	2.4	Cause	1
	2.5	CEO	2
	2.6	Code	2
	2.7	Committee	2
	2.8	Company	2
	2.9	Company Component	2
	2.10	Company Goals	2
	2.11	Disability	2
	2.12	Determination Year	2
	2.13	Determination Date	2
	2.14	Eligible Compensation	2
	2.15	Eligible Employee	2
	2.16	Effective Date	2
	2.17	Executive Officers	3
	2.18	Involuntary or Involuntarily	3
	2.19	Participant	3
	2.20	Payment Date	3
	2.21	Performance Component	3
	2.22	Performance Factor	3
	2.23	Plan	3
	2.24	Retire" or "Retirement	3
	2.25	Separates from Service, Separated from Service and Separation from Service	3
	2.26	Target Award	3
	2.27	Year of Service	3
ARTICLE III. PARTICIPATION			3
ARTICLE IV. DETERMINATION OF AWARDS			3
	4.1	Composition of Award	3
	4.2	Determination of Targets and Goals	4
	4.3	Attainment of Goals	4
	4.4	Adjustment of Target Awards	4
	4.5	Participant's Change in Status	5
	4.6	Final Discretion	5
ARTICLE V. PAYMENT			5
	5.1	Time and Form of Payment	5
	5.2	Payment Conditions	5
	5.3	Involuntary Separation Other Than for Cause	5
	5.4	Retirement, Death and Disability	5
ARTICLE VI. ADMINISTRATION			6
	6.1	Powers	6
	6.2	Determinations Binding	6
	6.3	Delegation	6
ARTICLE VII. GENERAL PROVISIONS			7
	7.1	No Continued Employment	7
	7.2	Non-transferability	7
	7.3	Taxes	7
	7.4	Other Benefits	7

i

	7.5	Source of Awards	7
	7.6	Successor and Assigns	7
	7.7	Recovery Policy	7
	7.8	Governing Law	8
	7.9	Severability	8
	7.10	Amendment and Termination	8
	7.11	Code Section 409A	8
	7.12	Arbitration	8
Exhibit A Allocation Matrix at Target Performance			10
Exhibit B Payout Multiplier Based on Individual Performance			11
Exhibit C Company Goals; Weightings for Company Goals			12
Exhibit D Payout Ranges for Company Goals			13

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CLECO CORPORATE HOLDINGS LLC

SHORT-TERM INCENTIVE PLAN

(Effective January 1, 2017)

Cleco Corporate Holdings LLC (the “Company”), hereby establishes this Short-Term Incentive Plan, subject to the terms and conditions set forth below (the “Plan”).

ARTICLE I.

PURPOSE

The purposes of the Plan are to: (a) provide annual cash incentives to officers and employees of the Company; (b) attract and retain officers and employees; and (c) further align the interests of employees and officers of the Company with the interests of its owners.

ARTICLE II.

DEFINITIONS

2.1Affiliate means any corporation or other form of entity of which the Company owns, from time to time, directly or indirectly, at least 50% of the total combined voting power of all classes of stock or other equity interests.

2.2Award means a cash payment made according to the terms and conditions of the Plan.

2.3Board means the Board of Managers of the Company.

2.4Cause means that a Participant has:

(a)Committed an intentional act of fraud, embezzlement or theft in the course of employment or otherwise engaged in any intentional misconduct which is materially injurious to the financial condition or business reputation of the Company or its Affiliates;

(b)Committed intentional damage to the property of the Company and its Affiliates or committed intentional wrongful disclosure of proprietary information or confidential information, which is materially injurious to the financial condition or business reputation of the Company or its Affiliates;

(c)Been convicted with no further possibility of appeal, or entered a guilty or nolo contendere plea, for a felony or a crime involving moral turpitude;

(d)Willfully and substantially refused to perform the essential duties of his or her position after written notice from the Company;

(e)Intentionally, recklessly or negligently violated any material provision of the Company's code of conduct or equivalent code or policy that is applicable to the Participant;

(f)Intentionally, recklessly or negligently acted or failed to act in a manner which materially compromises his or her ability to perform the essential duties of his or her position;

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(g)Intentionally, recklessly or negligently violated any material provision of the Sarbanes-Oxley Act of 2002 or any of the rules adopted by the Securities and Exchange Commission implementing any such provision; or

(h)Failed to fully cooperate to the extent requested by the Company or an Affiliate with investigations by government or independent agencies involving the Company or an Affiliate.

No act or failure to act on the part of a Participant will be deemed intentional if it was due primarily to an error in judgment or negligence, but will be deemed intentional only if done or omitted to be done by a Participant not in good faith and without reasonable belief that his or her action or omission was in the best interest of the Company or an Affiliate.

2.5CEO means the Chief Executive Officer of the Company.

2.6Code means the Internal Revenue Code of 1986, as amended, including any regulation, rule or other guidance promulgated thereunder.

2.7Committee means the Leadership Development & Compensation Committee that is appointed by the Board of Managers and that shall consist of not less than two persons.

2.8Company means Cleco Corporate Holdings LLC.

2.9Company Component is defined in Section 4.1.

2.10Company Goals means Company financial or operational metrics designated annually by the Committee, which metrics may include but not be limited to: safety, generation and distribution reliability, customer satisfaction, and milestone goals for key projects. Company Goals may relate to the Company or to an Affiliate, division, business unit or profit center thereof. A single Company Goal may be established with respect to all Participants hereunder, or goals may be established with respect to groups of Participants, whether by job title, classification or other reasonable method.

2.11Disability is defined in Section 5.4(a).

2.12Determination Year means the Company’s fiscal year during which the services giving rise to an Award hereunder are rendered;

2.13Determination Date means the last business day of the first quarter of each Determination Year.

2.14Eligible Compensation means total cash earnings for the Determination Year less any earnings not based on hours (e.g., previous year’s annual incentive, relocation allowance, meal reimbursement).

2.15Eligible Employee means a regular, full-time, employee of the Company and/or its Affiliates, including officers, determined according to the Company’s standard personnel policies and practices, but excluding individuals who are classified by the Company as leased or otherwise employed by a third party, independent contractors or intermittent or temporary employees, even if any such classification is modified by audit, administrative proceeding, litigation or otherwise.

2.16Effective Date means January 1, 2017.

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2.17Executive Officers means those officers of the Company who comprise the executive management team.

2.18Involuntary or Involuntarily means a Separation from Service because of the independent exercise of the unilateral authority of the Employer to terminate the Participant’s services, other than because of the Participant’s implicit or explicit request, if the Participant was willing and able to continue performing services.

2.19Participant is defined in Article III.

2.20Payment Date is defined in Section 5.1.

2.21Performance Component is defined in Section 4.1.

2.22Performance Factor is defined in Section 4.3.

2.23Plan means this Short-Term Incentive Plan, as it may be amended or restated from time to time.

2.24Retire or Retirement is defined in Section 5.4(b).

2.25Separates from Service, Separated from Service and Separation from Service refer to the later of the date on which (a) a Participant's employment with the Company and its Affiliates ceases, or (b) the Company and such Participant reasonably anticipate that he or she will perform no further services for the Company and its Affiliates, whether as a common law employee or independent contractor. Notwithstanding the foregoing, a Participant may be deemed to have Separated from Service if he or she continues to provide services to the Company or an Affiliate, whether as an employee or an independent contractor, provided such continuing services are not more than 20% of the average level of services performed by such Participant during the immediately preceding 36-month period.

2.26Target Award is defined in Section 4.2(a).

2.27Year of Service has the meaning given to that term by the separate defined benefit plan maintained by the Employer, without regard to whether the individual in question is eligible to participate in that plan.

ARTICLE III.

PARTICIPATION

Eligible Employees of the Company and its Affiliates shall be eligible to receive Awards hereunder, when designated by the Committee (each a “Participant”). Eligible Employees may be designated individually or by groups or categories, in the discretion of the Committee. Unless otherwise provided by the Committee with respect to a Determination Year, any such designation shall be made not later than the Determination Date.

ARTICLE IV.

DETERMINATION OF AWARDS

4.1Composition of Award: Each Participant’s Award hereunder shall equal the product of: (a) an amount attributable to the attainment of Company Goals (the “Company Component”), and (b) a

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multiplier attributable to the attainment of individual performance goals (the “Performance Component”). Such amounts shall be determined according to the provisions of this Section 4 and paid according to the provisions of Section 5 hereof.

4.2Determination of Targets and Goals: Not later than each Determination Date, the Committee:

(a)Shall determine the percentage of each Participant’s Eligible Compensation that may be payable as an Award hereunder (a “Target Award”);

(b)Shall determine the Company Goals applicable for the Determination Year;

(c)Shall determine as to each Participant, the percentage of his or her aggregate Award that shall constitute the Company Component and a multiplier that shall constitute the Performance Component, which determinations shall be set forth on Exhibit A hereto, as the same may be modified from time to time.

(d)May specify a threshold level below which no Award shall be made and a maximum level above which no additional Award shall be made. Such threshold and maximum levels may be imposed with respect to Company Goals or the aggregate amount of any Award hereunder.

Any determination hereunder shall be made, in writing, and shall be communicated to each Participant not later than the Determination Date, or as soon as practicable thereafter. The Committee directs the CEO to delegate to the appropriate officers, managers and supervisors of the Company the authority to determine individual performance goals hereunder; provided, however, that no such delegation shall be made with respect to the Company’s Executive Officers. The CEO shall directly determine the individual performance goals of the Executive Officers.

4.3Attainment of Goals. As of the last day of each Determination Year, or as soon as practicable thereafter, the Committee shall determine whether and to what extent the Company Goals applicable with respect to such year have been attained. The Committee, or one or more of its designees, shall further determine with respect to each Participant hereunder whether and to what extent individual performance goals have been attained with respect to such year, which determination shall be expressed as a numerical rating (a “Performance Factor”), as more fully set forth on Exhibit B hereto, as the same may be modified from time to time.

Determinations hereunder shall be made in writing and communicated to each affected Participant as soon as practicable following the last day of each Determination Year.

4.4Adjustment of Target Awards. Once established, the Committee shall have the discretion to change, adjust, or amend Company Goals on account of changed circumstances. For example, at any time before the final determination of Awards, the Committee may equitably adjust the Company Goals to reflect:

(a)a change in entity capitalization, or an entity level transaction (such as a merger, consolidation, separation, reorganization or partial or complete liquidation),

(b)the occurrence of any extraordinary event or unforeseen occurrence, or

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(c)any change in applicable accounting rules or principles, any change in the Company’s or an Affiliate’s accounting method, or any change in applicable law.

4.5Participant’s Change in Status.If during a Determination Year a Participant is promoted or demoted after the Determination Date when the Participant’s sharing percentage for that Determination Year has been established, such Participant's Target Award shall be based on the position the Participant held on September 30 of the Determination Year. If the individual becomes a Participant during a Determination Year, the individual's Award shall be based on the Participant's Eligible Compensation during the portion of the Determination Year during which the individual was a Participant. If the individual was a Participant for the entire Determination Year but the individual's Compensation changes during the Determination Year, the Participant's Award shall be based on the Participant's actual Eligible Compensation during the entire Determination Year, taking into account the Participant's old and new rates.

4.6Final Discretion. Notwithstanding any provision of this Plan to the contrary, the Committee shall possess the final discretion to adjust the amount of any Award determined and payable hereunder, which adjustment may be made with respect to the total Award or either component thereof. Designees of the Committee, including appropriate officers, managers and supervisors, shall further possess the discretion to adjust the amount of any Award payable hereunder; provided that delegation of such discretion shall not be made with respect to the Company’s Executive Officers, who shall be evaluated either by the CEO or the Committee.

ARTICLE V.

PAYMENT

5.1Time and Form of Payment. Awards hereunder shall be paid in the form of a single sum no later than the 15th day of the third calendar month following the end of each Determination Year (the “Payment Date”).

5.2Payment Conditions. Except as expressly provided in Section 5.3, a Participant must be employed by the Company or an Affiliate on the last day of the Determination Yearas a condition of the receipt of an Award hereunder. Except as provided in Sections 5.3 and 5.4, a Participant will forfeit any Award with respect to a Determination Year if the Participant Separates from Service with the Company before the end of a Determination Year or if the Participant Separates from Service during that Determination Year for Cause (regardless of whether the Separation from Service was Involuntary or voluntary at the Company's request).

5.3Involuntary Separation Other Than for Cause. Notwithstanding the provisions of Section 5.2 hereof, if a Participant Separates from Service with the Company and all Affiliates during a Determination Year Involuntarily other than for Cause, the Committee shall have the discretion to determine payment hereunder. Payment, if any, shall be based only on the Participant's Eligible Compensation during the period preceding the Participant's Separation from Service (rather than the Eligible Compensation the Participant would have earned had the Participant remained employed for the entire Determination Year). Such amount as so computed shall be paid as of the Payment Date otherwise applicable to such Award.

5.4Retirement, Death and Disability. Notwithstanding the provisions of Section 5.2 hereof and unless the Committee otherwise provides, if a Participant Separates from Service with the Company and all Affiliates during a Determination Year on account of his or her death, Disability or Retirement, the Award otherwise payable to such Participant with respect to such year shall be based only on the Eligible Compensation that was actually paid to the Participant with respect to the period preceding

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the Participant's Separation from Service (rather than based on the annualized Eligible Compensation the Participant would have earned had the Participant remained employed for the entire Determination Year). Such amount as so computed shall be paid as of the Payment Date otherwise applicable to such Award. For this purpose:

(a)The term “Disability” means that a Participant is receiving long-term disability benefits under a separate plan or policy maintained by the Company.

(b)The term “Retirement” or “Retire” means the Committee determined that the Participant Separated from Service from the Employer other than for Cause (regardless of whether the Separation from Service was Involuntary or voluntary at the Company's request) and that the Participant met one of the following conditions:

(1)the Participant Separated from Service after reaching age 55 with at least 10 Years of Service;

(2)the Participant Separated from Service after reaching age 60 with at least 5 Years of Service; or

(3)the Participant Separated from Service after reaching age 65.

ARTICLE VI.

ADMINISTRATION

6.1Powers. All powers granted to the Committee hereunder are subject to the approval and direction of the Board. In addition to the power and authority provided elsewhere in this Plan, the Committee shall have the discretionary power and authority to:

(a)designate Participants hereunder;

(b)determine Company Goals and Performance Goals;

(c)determine the amount of any Award finally payable hereunder;

(d)construe and interpret the provisions of the Plan and any form or agreement related thereto;

(e)establish and adopt such rules, regulations, and procedures as may be necessary or advisable in connection with the administration of the Plan; and

(f)make any other determination it believes necessary or advisable for the proper administration of the Plan.

6.2Determinations Binding. Determinations,decisions, interpretations and actions of the Committee concerning matters related to the Plan shall be final and conclusive on the Company, its Affiliates and Participants and their beneficiaries or heirs. The Committee may make determinations selectively among Participants who receive or are eligible to receive Awards hereunder, whether or not such Participants are similarly situated.

6.3Delegation. Through the CEO or otherwise, the Committee may delegate to the appropriate officers, managers and supervisors of the Company any portion of the administrative

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authority afforded to it hereunder; provided that no such delegation shall be made with respect to the Company’s Executive Officers, who shall be addressed either by the CEO or the Committee.

ARTICLE VII.

GENERAL PROVISIONS

7.1No Continued Employment. Participation in this Plan shall not confer on any Participant the right to continue in the employ of the Company or an Affiliate for any period of time or any right to continue at his or her present or any other rate of compensation or job classification.

7.2Non-transferability. No Award, or the expectation to receive an Award, shall be subject to transfer, pledge, assignment, hypothecation, or alienation or otherwise be encumbered or disposed of by a Participant hereunder, whether by operation of law or otherwise, whether voluntarily or involuntarily (except if a Participant dies or by will or the laws of descent and distribution). Neither the Committee nor the Company shall be required to recognize any attempted assignment of such rights by any Participant or his or her heirs or beneficiaries.

7.3Taxes. The Company shall withhold from any Award hereunder any taxes or other amounts required by law to be withheld.

7.4Other Benefits. Awards hereunder shall not impair or otherwise reduce a Participant’s compensation, life insurance, retirement or other benefits provided by the Company or its Affiliates; provided, however, that the value of any Award hereunder shall not be treated as compensation for purposes of computing the value or amount of any such benefit unless otherwise provided in the separate plan or policy providing for the establishment and administration of such benefit.

7.5Source of Awards. Awards hereunder shall be made from the Company’s general assets. The status of any Participant with respect to an Award hereunder shall be that of a general unsecured creditor of the Company, and no Participant shall have any right, title, or interest in or to any asset of the Company. Nothing contained in this Plan shall be deemed or be construed to create a trust of any kind or other fiduciary relationship between the Company and Participant or any other person.

7.6Successors and Assigns. Any obligation of the Company hereunder shall be binding on and inure to the benefit of its successors and assigns; any such obligation shall inure to the benefit of and be binding on each Participant, including his or her heirs, estate, succession, legatees and legal representative. If a Participant dies before an Award is paid hereunder, payment shall be made to his or her surviving spouse or estate, as determined in the discretion of the Committee.

7.7Recovery Policy. Any Award hereunder shall be subject to the terms of any compensation recovery agreement or policy or policies established by the Company, as may be in effect from time to time and with respect to which a Participant is a party or is bound. In addition, if the Company or an Affiliate is required to restate its financial statements or other financial results, the Committee may take such action as it deems necessary or appropriate, to the extent consistent with applicable law, to cause the reduction, forfeiture or recovery of any payment with respect to an Award, provided that:

(a)the amount of such payment was predicated, directly or indirectly, on the achievement of financial statement measures or results that were subject to material restatement;

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(b)the affected Participant was grossly negligent or engaged in intentional misconduct or an intentional act or omission, as determined by the Committee in connection with the restatement; and

(c)the amount of any such payments would have been lesser if it had been based upon the restated results.

7.8Governing Law. Except to the extent preempted by federal law, the Plan shall be construed and interpreted according to the internal laws of the State of Louisiana, without regard to the conflicts of law provisions thereof.

7.9Severability. The invalidity or unenforceability of any provision hereof shall in no way affect the validity or enforceability of any other provision.

7.10Amendment and Termination. Except as provided herein, the Company has no obligation to maintain this Plan for any particular length of time. The Committee retains the right, at any time, to amend or terminate this Plan, in whole or in part, by providing 30 days prior email or other similar written notice to each affected Participant hereunder. Notwithstanding the foregoing: (a) no amendment or termination shall impair an Award otherwise payable with respect to a Determination Year, as determined before the adoption or effective date of any such amendment or termination, and (b) prior written notice shall not be required with respect to the modification of any exhibit hereto.

7.11Code Section 409A. It is intended that Awards hereunder shall be excluded from the provisions of Code Section 409A under the short-term deferral exclusion available thereunder, and that the provisions and administration of this Plan shall be interpreted, construed and conducted according to such exclusion. Nevertheless, should any individual Award be deemed deferred compensation subject to the provisions of Code Section 409A, such Award shall be administered according to the applicable provisions of such section.

7.12Arbitration. Notwithstanding Section 6.2, if any other issue or dispute arises under this Plan, then any such matter shall be referred to arbitration under this provision. As a condition of the receipt of an Award, each Participant shall be deemed to agree that any dispute or controversy that arises hereunder shall be resolved by arbitration. Any arbitration proceeding shall be conducted according to the employment rules of the American Arbitration Association (“AAA”). Any dispute or claim shall be presented to a single arbitrator selected by the mutual agreement of the parties (or the arbitrator will be selected according to the rules of the AAA). All determinations of the arbitrator will be final and binding. Each party to the arbitration proceeding will bear its own costs in connection with the proceedings, except that the costs and expenses of the arbitrator will be divided evenly between the parties. The venue for any arbitration proceeding and for any judicial proceeding related to this arbitration provision (including a judicial proceeding to enforce this provision) will be in Pineville, Louisiana.

THIS SHORT-TERM INCENTIVE PLAN was adopted by Cleco Corporate Holdings LLC effective as of January 1, 2017, on the date indicated below.

CLECO CORPORATE HOLDINGS LLC

By:        /s/ Chris Leslie                                     

Date     May 9, 2017                                           

2017 Short-Term Incentive Plan Page 8

Exhibits:

Exhibit A - Allocation Matrix

Exhibit B - Payout Multiplier Based on Individual Performance

Exhibit C - Company Goals; Weightings for Company Goals

Exhibit D - Payout Ranges for Company Goals

2017 Short-Term Incentive Plan Page 9

CLECO CORPORATE HOLDINGS LLC

SHORT-TERM INCENTIVE PLAN

Exhibit A

Allocation Matrix at Target Performance

Effective as of January 1, 2017

Employee Group	Financial Company Goal Weighting	Milestone Goal Weighting	Operational Company Goal Weighting
CEO	40%	20%	40%
Officers (EMT)	40%	20%	40%
Officers (VPs)	60%	NA	40%
General Managers	60%	NA	40%
Managers and Supervisors	60%	NA	40%
Exempt	60%	NA	40%
Non-Exempt	60%	NA	40%

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CLECO CORPORATE HOLDINGS LLC

SHORT-TERM INCENTIVE PLAN

Exhibit B

Payout Multiplier Based on Individual Performance

Effective January 1, 2017

Performance Factor	Description	Payout Multiplier Based on Individual Performance
1	Superior Performance exceeds expectations and goals; consistently makes contributions beyond goals and expectations.	111% - 130%
2	Successful Fully and consistently meets goals and expectations. Fully competent.	76% - 110%
3	Inconsistent Needs improvement to reach competent level.	0% - 75%

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CLECO CORPORATE HOLDINGS LLC

SHORT-TERM INCENTIVE PLAN

Exhibit C

Company Goals; Weightings for Company Goals

Effective January 1, 2017for the Determination Year ending December 31, 2017

Company Goal	CEO and EMT Members	All Other Employees
Earnings Before Income Taxes, Interest and Depreciation (EBITDA)	40%	60%
Milestone Goals	20%	NA
Safety - DART (Days Away, Restricted or Transferred) and TRIR (Total Recordable Incident Rate)	10%	10%
Equivalent Forced Outage Rate (EFORd)	10%	10%
System Average Interruption Duration Index (SAIDI)	10%	10%
Customer Satisfaction	10%	10%
TOTAL	100%	100%

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CLECO CORPORATE HOLDINGS LLC

SHORT-TERM INCENTIVE PLAN

Exhibit D

Payout Ranges for Company Goals

Effective January 1, 2017for the Determination Year ending December 31, 2017

Company Goal	Target	Performance/Payout Ranges
Earnings Before Income Taxes, Interest and Depreciation (EBITDA)	$459.8MM	Below $425.3M - 0% At $425.3M - 50% $459.8M - 100% At or above $494.3MM - 200% (Payouts for performance between the stated ranges will be interpolated)
Safety - DART	0.306 - 0.227	Above 0.385 - 0% 0.385 - 0.307 - 50% 0.306 - 0.227 - 100% 0.226 - 0.146 - 150% 0.145 and below - 200%
Safety - TRIR	0.730 - 0.575	Above 0.885 - 0% 0.885 - 0.731 - 50% 0.730 - 0.575 - 100% 0.574 - 0.420 - 150% 0.419 and below - 200%
Equivalent Forced Outage Rate (EFORd)	5.68% - 5.37%	Above 6.00% - 0% 6.00% - 5.69% - 50% 5.68% - 5.37% - 100% 5.36% - 5.06% - 150%  5.05% and below - 200%
System Average Interruption Duration Index (SAIDI)	2.57 - 2.42	Above 2.73 - 0% 2.73 - 2.58 - 50% 2.57 - 2.42 - 100% 2.41 - 2.27 - 150% 2.26 and below - 200%
Customer Satisfaction	683 - 707	Below 658 - 0% 658 - 682 - 50% 683 - 707 - 100% 708 - 732 - 150% 733 and above - 200%
TOTAL

2017 Short-Term Incentive Plan Page 13

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 THREE MONTHS ENDED MAR. 31, 2017			APR. 13, 2016 - DEC. 31, 2016			JAN. 1, 2016 - APR. 12, 2016			FOR THE TWELVE MONTHS ENDED DEC. 31, 2015			FOR THE TWELVE MONTHS ENDED DEC. 31, 2014			FOR THE TWELVE MONTHS ENDED DEC. 31, 2013
Net income (loss)	$	6,292		$	(24,113	)	$	(3,960	)	$	133,669		$	154,739		$	160,685
Income tax expense (benefit)	3,107			(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)	32,108			91,338			22,547			79,795			76,163			86,680
Total earnings	$	41,507		$	44,403		$	22,055		$	291,175		$	298,095		$	327,248
Fixed charges
Interest	$	29,920		$	87,315		$	21,491		$	75,535		$	71,959		$	81,173
Amortization of debt expense, premium, net	2,025			3,537			839			3,342			3,227			4,397
Portion of rentals representative of an interest factor**	139			362			146			572			489			488
Interest of capitalized lease	24			124			71			346			488			622
Total fixed charges	$	32,108		$	91,338		$	22,547		$	79,795		$	76,163		$	86,680
Ratio of earnings to fixed charges	1.29		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 THREE MONTHS ENDED MAR. 31, 2017			FOR THE TWELVE MONTHS ENDED DEC. 31, 2016			FOR THE TWELVE MONTHS ENDED DEC. 31, 2015			FOR THE TWELVE MONTHS ENDED DEC. 31, 2014			FOR THE TWELVE MONTHS ENDED DEC. 31, 2013
Net income	$	17,854		$	39,128		$	141,350		$	154,316		$	150,410
Income tax expense	9,855			18,369			79,294			76,974			79,381
Total fixed charges (from below)	18,494			78,442			78,364			77,230			85,103
Total earnings	$	46,203		$	135,939		$	299,008		$	308,520		$	314,894
Fixed charges
Interest	$	16,619		$	74,450		$	74,394		$	73,140		$	80,905
Amortization of debt expense, premium, net	1,712			3,289			3,052			3,113			3,088
Portion of rentals representative of an interest factor**	139			508			572			489			488
Interest of capitalized lease	24			195			346			488			622
Total fixed charges	$	18,494		$	78,442		$	78,364		$	77,230		$	85,103
Ratio of earnings to fixed charges	2.50		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 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:   May 11, 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 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:   May 11, 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 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:  May 11, 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 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:   May 11, 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 March 31, 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:   May 11, 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 March 31, 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:   May 11, 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 March 31, 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:   May 11, 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 March 31, 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:  May 11, 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 first quarter of 2017, DHLC was issued one non significant and substantial citation. The amount assessed was immaterial. No significant and substantial citations were issued during this same time period. However, during the first quarter of 2017, DHLC was assessed for three citations issued during 2016, one of which was classified as significant and substantial. This amount was also 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	3 Months Ended
	Mar. 31, 2017	May 11, 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	Mar. 31, 2017
Document Fiscal Year Focus	2017
Document Fiscal Period Focus	Q1
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
	Mar. 31, 2017	Mar. 31, 2016
Interest charges [Abstract]
Net (loss) income	$ 6,292
Cleco Power [Member]
Operating revenue [Abstract]
Electric operations	237,553	$ 250,157
Other operations	16,365	16,614
Affiliate revenue	219	232
Gross operating revenue	254,137	267,003
Electric customer credits	(435)	(321)
Operating revenue, net	253,702	266,682
Operating expenses [Abstract]
Fuel used for electric generation	69,873	87,443
Power purchased for utility customers	31,963	23,105
Other operations	31,988	29,399
Maintenance	24,420	24,538
Depreciation and amortization	38,758	38,603
Taxes other than income taxes	12,000	12,424
Gain on sale of asset	0	(1,095)
Total operating expenses	209,002	214,417
Operating (loss) income	44,700	52,265
Interest income	266	179
Allowance for equity funds used during construction	911	652
Other income	210	148
Other expense	(274)	(517)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	18,331	19,470
Allowance for borrowed funds used during construction	(227)	(185)
Total interest charges	18,104	19,285
(Loss) income before income taxes	27,709	33,442
Federal and state income tax (benefit) expense	9,855	12,563
Net (loss) income	17,854	20,879
Predecessor [Member]
Operating revenue [Abstract]
Electric operations		250,157
Other operations		17,132
Affiliate revenue		0
Gross operating revenue		267,289
Electric customer credits		(321)
Operating revenue, net		266,968
Operating expenses [Abstract]
Fuel used for electric generation		87,443
Power purchased for utility customers		23,105
Other operations		29,325
Maintenance		24,631
Depreciation and amortization		38,938
Taxes other than income taxes		12,907
Merger transaction and commitment costs		1,522
Gain on sale of asset		(1,095)
Total operating expenses		216,776
Operating (loss) income		50,192
Interest income		224
Allowance for equity funds used during construction		652
Other income		506
Other expense		(516)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net		19,738
Allowance for borrowed funds used during construction		(185)
Total interest charges		19,553
(Loss) income before income taxes		31,505
Federal and state income tax (benefit) expense		12,137
Net (loss) income		$ 19,368
Successor [Member]
Operating revenue [Abstract]
Electric operations	234,056
Other operations	16,880
Affiliate revenue	0
Gross operating revenue	250,936
Electric customer credits	(435)
Operating revenue, net	250,501
Operating expenses [Abstract]
Fuel used for electric generation	69,873
Power purchased for utility customers	31,963
Other operations	31,892
Maintenance	24,523
Depreciation and amortization	40,851
Taxes other than income taxes	12,502
Merger transaction and commitment costs	99
Gain on sale of asset	0
Total operating expenses	211,703
Operating (loss) income	38,798
Interest income	312
Allowance for equity funds used during construction	911
Other income	1,370
Other expense	(274)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	31,945
Allowance for borrowed funds used during construction	(227)
Total interest charges	31,718
(Loss) income before income taxes	9,399
Federal and state income tax (benefit) expense	3,107
Net (loss) income	$ 6,292

XML

Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Net (loss) income	$ 6,292
Other comprehensive (loss) income, net of tax [Abstract]
Total other comprehensive (loss) income, net of tax	(2,191)
Cleco Power [Member]
Net (loss) income	17,854	$ 20,879
Other comprehensive (loss) income, net of tax [Abstract]
Postretirement benefits (loss) gain, net of tax	(420)	200
Net gain on cash flow hedges, net of tax	53	53
Total other comprehensive (loss) income, net of tax	(367)	253
Comprehensive (loss) income, net of tax	17,487	21,132
Successor [Member]
Net (loss) income	6,292
Other comprehensive (loss) income, net of tax [Abstract]
Postretirement benefits (loss) gain, net of tax	(2,191)
Net gain on cash flow hedges, net of tax	0
Total other comprehensive (loss) income, net of tax	(2,191)
Comprehensive (loss) income, net of tax	$ 4,101
Predecessor [Member]
Net (loss) income		19,368
Other comprehensive (loss) income, net of tax [Abstract]
Postretirement benefits (loss) gain, net of tax		528
Net gain on cash flow hedges, net of tax		53
Total other comprehensive (loss) income, net of tax		581
Comprehensive (loss) income, net of tax		$ 19,949

XML

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cleco Power [Member]
Net tax expense (benefit) of gain (loss) on postretirement benefits	$ (262)	$ 125
Net tax expense on cash flow hedges	33	33
Successor [Member]
Net tax expense (benefit) of gain (loss) on postretirement benefits	(1,370)
Net tax expense on cash flow hedges	$ 0
Predecessor [Member]
Net tax expense (benefit) of gain (loss) on postretirement benefits		330
Net tax expense on cash flow hedges		$ 33

XML

Consolidated Balance Sheets - USD ($)	Mar. 31, 2017	Dec. 31, 2016
Current assets [Abstract]
Cash and cash equivalents	$ 21,519,000	$ 23,077,000
Restricted cash and cash equivalents	14,150,000	23,084,000
Customer accounts receivable (less allowance for doubtful accounts)	45,342,000	56,780,000
Other accounts receivable	21,191,000	19,778,000
Unbilled revenue	29,504,000	34,268,000
Fuel inventory, at average cost	52,658,000	46,410,000
Materials and supplies, at average cost	83,301,000	81,818,000
Energy risk management assets	4,957,000	7,884,000
Accumulated deferred fuel	24,212,000	20,787,000
Cash surrender value of company-/trust-owned life insurance policies	78,927,000	77,225,000
Prepayments	7,497,000	7,813,000
Regulatory assets	26,476,000	26,803,000
Other current assets	423,000	1,315,000
Total current assets	410,157,000	427,042,000
Property, plant, and equipment [Abstract]
Property, plant, and equipment	3,506,239,000	3,476,581,000
Accumulated depreciation	(98,969,000)	(75,816,000)
Net property, plant, and equipment	3,407,270,000	3,400,765,000
Construction work in progress	99,113,000	78,577,000
Total property, plant, and equipment, net	3,506,383,000	3,479,342,000
Equity investment in investees	18,672,000	18,672,000
Goodwill	1,490,797,000	1,490,797,000
Prepayments	4,874,000	4,731,000
Restricted cash and cash equivalents	23,554,000	23,410,000
Regulatory assets - deferred taxes, net	238,378,000	237,449,000
Regulatory assets	445,200,000	454,644,000
Net investment in direct financing lease	13,407,000	13,420,000
Intangible assets	135,591,000	142,634,000
Tax credit fund investment, net	12,138,000	11,888,000
Other deferred charges	36,830,000	39,115,000
Total assets	6,335,981,000	6,343,144,000
Current liabilities [Abstract]
Short-term debt	541,000	0
Long-term debt due within one year	19,689,000	19,715,000
Accounts payable	95,307,000	112,087,000
Customer deposits	56,972,000	56,599,000
Provision for rate refund	3,262,000	3,974,000
Provision for merger commitments	10,999,000	14,371,000
Taxes payable	16,510,000	3,942,000
Interest accrued	40,447,000	14,783,000
Energy risk management liabilities	539,000	201,000
Deferred compensation	10,787,000	11,654,000
Other current liabilities	14,922,000	14,850,000
Total current liabilities	269,975,000	252,176,000
Long-term liabilities and deferred credits [Abstract]
Accumulated deferred federal and state income taxes, net	1,035,656,000	1,033,055,000
Accumulated deferred investment tax credits	2,585,000	2,751,000
Postretirement benefit obligations	227,777,000	223,003,000
Restricted storm reserve	17,643,000	17,385,000
Other deferred credits	33,740,000	29,440,000
Total long-term liabilities and deferred credits	1,317,401,000	1,305,634,000
Long-term debt, net	2,726,696,000	2,738,571,000
Total liabilities	4,314,072,000	4,296,381,000
Commitments and Contingencies (Note 12)
Member's equity [Abstract]
Membership interest	2,040,421,000	2,069,376,000
Accumulated deficit	(17,821,000)	(24,113,000)
Accumulated other comprehensive (loss) income	(691,000)	1,500,000
Total member’s equity	2,021,909,000	2,046,763,000
Total liabilities and member’s equity	6,335,981,000	6,343,144,000
Cleco Power [Member]
Current assets [Abstract]
Cash and cash equivalents	21,164,000	21,482,000
Restricted cash and cash equivalents	14,150,000	23,084,000
Customer accounts receivable (less allowance for doubtful accounts)	45,342,000	56,780,000
Accounts receivable - affiliate	1,378,000	1,406,000
Other accounts receivable	21,161,000	19,457,000
Taxes receivable, net	721,000	12,490,000
Unbilled revenue	29,504,000	34,268,000
Fuel inventory, at average cost	52,658,000	46,410,000
Materials and supplies, at average cost	83,301,000	81,818,000
Energy risk management assets	4,957,000	7,884,000
Accumulated deferred fuel	24,212,000	20,787,000
Cash surrender value of company-/trust-owned life insurance policies	20,090,000	20,018,000
Prepayments	5,969,000	5,892,000
Regulatory assets	17,618,000	17,721,000
Other current assets	0	577,000
Total current assets	342,225,000	370,074,000
Property, plant, and equipment [Abstract]
Property, plant, and equipment	4,815,466,000	4,790,565,000
Accumulated depreciation	(1,634,875,000)	(1,618,241,000)
Net property, plant, and equipment	3,180,591,000	3,172,324,000
Construction work in progress	97,776,000	77,306,000
Total property, plant, and equipment, net	3,278,367,000	3,249,630,000
Equity investment in investees	18,672,000	18,672,000
Prepayments	4,874,000	4,731,000
Restricted cash and cash equivalents	23,533,000	23,389,000
Regulatory assets - deferred taxes, net	238,378,000	237,449,000
Regulatory assets	261,858,000	268,016,000
Intangible assets	54,991,000	58,473,000
Other deferred charges	34,808,000	37,014,000
Total assets	4,257,706,000	4,267,448,000
Current liabilities [Abstract]
Long-term debt due within one year	19,689,000	19,715,000
Accounts payable	88,994,000	101,874,000
Accounts payable - affiliate	9,367,000	7,190,000
Customer deposits	56,972,000	56,599,000
Provision for rate refund	3,262,000	3,974,000
Provision for merger commitments	10,999,000	14,371,000
Interest accrued	21,371,000	7,141,000
Energy risk management liabilities	539,000	201,000
Other current liabilities	10,004,000	9,951,000
Total current liabilities	221,197,000	221,016,000
Long-term liabilities and deferred credits [Abstract]
Accumulated deferred federal and state income taxes, net	1,079,427,000	1,068,592,000
Accumulated deferred investment tax credits	2,585,000	2,751,000
Postretirement benefit obligations	161,257,000	159,107,000
Restricted storm reserve	17,643,000	17,385,000
Other deferred credits	31,813,000	28,339,000
Total long-term liabilities and deferred credits	1,292,725,000	1,276,174,000
Long-term debt, net	1,226,095,000	1,235,056,000
Total capitalization	2,743,784,000	2,770,258,000
Commitments and Contingencies (Note 12)
Member's equity [Abstract]
Total member’s equity	1,517,689,000	1,535,202,000
Total liabilities and member’s equity	$ 4,257,706,000	$ 4,267,448,000

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Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Current assets [Abstract]
Customer accounts receivable, allowance for doubtful accounts	$ 8,056	$ 7,199
Cleco Power [Member]
Current assets [Abstract]
Customer accounts receivable, allowance for doubtful accounts	$ 8,056	$ 7,199

XML

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Operating activities [Abstract]
Net (loss) income	$ 6,292
Financing activities [Abstract]
Cash and cash equivalents at beginning of period	23,077
Cash and cash equivalents at end of period	21,519
Predecessor [Member]
Operating activities [Abstract]
Net (loss) income		$ 19,368
Adjustments to reconcile net income (loss) to net cash provided by operating activities [Abstract]
Depreciation and amortization		40,285
Gain on sale of asset		(1,095)
Allowance for equity funds used during construction		(652)
Deferred income taxes		8,770
Deferred fuel costs		719
Cash surrender value of company-/trust-owned life insurance		(484)
Changes in assets and liabilities [Abstract]
Accounts receivable		3,129
Unbilled revenue		1,207
Fuel inventory and materials and supplies		17,725
Prepayments		2,076
Accounts payable		(21,379)
Customer deposits		2,877
Provision for merger commitments		0
Postretirement benefit obligations		2,630
Regulatory assets and liabilities, net		4,582
Other deferred accounts		5,529
Taxes accrued		12,651
Interest accrued		16,037
Other operating		2,257
Net cash provided by operating activities		116,232
Investing activities [Abstract]
Additions to property, plant, and equipment		(35,476)
Allowance for equity funds used during construction		652
Proceeds from sale of property		1,909
Contributions to equity investment in investee		(2,450)
Transfer of cash (to) from restricted accounts, net		4,088
Other investing		43
Net cash used in investing activities		(31,234)
Financing activities [Abstract]
Draws on credit facilities		3,000
Payments on credit facilities		(10,000)
Repayment of long-term debt		(8,546)
Dividends paid on common stock		(24,579)
Distributions to parent		0
Other financing		(673)
Net cash provided by (used in) financing activities		(40,798)
Net (decrease) increase in cash and cash equivalents		44,200
Cash and cash equivalents at beginning of period		68,246
Cash and cash equivalents at end of period		112,446
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized		2,460
Income taxes paid (refunded), net		(481)
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment		11,874
Successor [Member]
Operating activities [Abstract]
Net (loss) income	6,292
Adjustments to reconcile net income (loss) to net cash provided by operating activities [Abstract]
Depreciation and amortization	46,727
Gain on sale of asset	0
Allowance for equity funds used during construction	(911)
Deferred income taxes	3,041
Deferred fuel costs	(2,982)
Cash surrender value of company-/trust-owned life insurance	(1,702)
Changes in assets and liabilities [Abstract]
Accounts receivable	8,346
Unbilled revenue	4,765
Fuel inventory and materials and supplies	(7,733)
Prepayments	1,318
Accounts payable	(27,148)
Customer deposits	2,622
Provision for merger commitments	(3,866)
Postretirement benefit obligations	1,213
Regulatory assets and liabilities, net	2,599
Other deferred accounts	1,920
Taxes accrued	12,568
Interest accrued	25,620
Other operating	2,093
Net cash provided by operating activities	74,782
Investing activities [Abstract]
Additions to property, plant, and equipment	(47,890)
Allowance for equity funds used during construction	911
Proceeds from sale of property	242
Contributions to equity investment in investee	0
Transfer of cash (to) from restricted accounts, net	8,790
Other investing	(165)
Net cash used in investing activities	(38,112)
Financing activities [Abstract]
Draws on credit facilities	0
Payments on credit facilities	0
Repayment of long-term debt	(9,060)
Dividends paid on common stock	0
Distributions to parent	(28,955)
Other financing	(213)
Net cash provided by (used in) financing activities	(38,228)
Net (decrease) increase in cash and cash equivalents	(1,558)
Cash and cash equivalents at beginning of period	23,077
Cash and cash equivalents at end of period	21,519
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized	4,011
Income taxes paid (refunded), net	1
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment	27,617
Cleco Power [Member]
Operating activities [Abstract]
Net (loss) income	17,854	20,879
Adjustments to reconcile net income (loss) to net cash provided by operating activities [Abstract]
Depreciation and amortization	40,871	39,774
Gain on sale of asset	0	(1,095)
Allowance for equity funds used during construction	(911)	(652)
Deferred income taxes	10,135	1,854
Deferred fuel costs	(2,982)	719
Changes in assets and liabilities [Abstract]
Accounts receivable	8,064	3,130
Accounts and notes receivable, affiliate	471	1,716
Unbilled revenue	4,765	1,207
Fuel inventory and materials and supplies	(7,733)	17,725
Prepayments	925	1,560
Accounts payable	(23,836)	(20,581)
Accounts and notes payable, affiliate	2,083	731
Customer deposits	2,622	2,877
Provision for merger commitments	(3,866)	0
Postretirement benefit obligations	1,026	1,189
Regulatory assets and liabilities, net	2,103	4,582
Other deferred accounts	1,494	5,529
Taxes accrued	11,769	10,859
Interest accrued	14,230	16,078
Other operating	2,095	2,176
Net cash provided by operating activities	81,179	110,257
Investing activities [Abstract]
Additions to property, plant, and equipment	(46,744)	(35,453)
Allowance for equity funds used during construction	911	652
Proceeds from sale of property	242	1,909
Contributions to equity investment in investee	0	(2,450)
Transfer of cash (to) from restricted accounts, net	8,790	4,088
Other investing	39	43
Net cash used in investing activities	(36,762)	(31,211)
Financing activities [Abstract]
Repayment of long-term debt	(9,060)	(8,546)
Distributions to parent	(35,000)	(25,000)
Other financing	(675)	(657)
Net cash provided by (used in) financing activities	(44,735)	(34,203)
Net (decrease) increase in cash and cash equivalents	(318)	44,843
Cash and cash equivalents at beginning of period	21,482	65,705
Cash and cash equivalents at end of period	21,164	110,548
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized	2,212	2,334
Income taxes paid (refunded), net	0	(485)
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment	$ 27,493	$ 11,849

XML

Consolidated Statement of Changes in Equity - USD ($) $ in Thousands	Total	Membership Interest [Member]	Accumulated Deficit [Member]	AOCI [Member]	Cleco Power [Member]	Cleco Power [Member] Member's Equity [Member]	Cleco Power [Member] AOCI [Member]
Balances at Dec. 31, 2015							$ (17,092)
Increase (Decrease) in Equity [Roll Forward]
Net (loss) income					$ 20,879
Other comprehensive loss, net of tax					253		253
Balances at Mar. 31, 2016							(16,839)
Balances 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 made to member	(28,955)	(28,955)			(35,000)	(35,000)
Net (loss) income	6,292		6,292		17,854	17,854
Other comprehensive loss, net of tax	(2,191)			(2,191)	(367)		(367)
Balances at Mar. 31, 2017	$ 2,021,909	$ 2,040,421	$ (17,821)	$ (691)	$ 1,517,689	$ 1,531,478	$ (13,789)

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Summary of Significant Accounting Policies

3 Months Ended

Mar. 31, 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 and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Basis of Presentation

The Condensed Consolidated Financial Statements of Cleco Holdings 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 present the financial position and results of operations of Cleco. Amounts reported in Cleco’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 $1.00per 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.

Restricted Cash and Cash Equivalents

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

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

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,432	$	9,213
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	9,518		12,671
Total current	14,150		23,084
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	17,576		17,379
Cleco Power’s charitable contributions	4,126		4,179
Cleco Power’s rate credit escrow	1,831		1,831
Total non-current	23,554		23,410
Total restricted cash and cash equivalents	$	37,704	$	46,494

Cleco Power
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,432	$	9,213
Charitable contributions	1,200		1,200
Rate credit escrow	9,518		12,671
Total current	14,150		23,084
Non-current
Future storm restoration costs	17,576		17,379
Charitable contributions	4,126		4,179
Rate credit escrow	1,831		1,831
Total non-current	23,533		23,389
Total restricted cash and cash equivalents	$	37,683	$	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 March 31, 2017, was due to Cleco Katrina/Rita using $9.1 million for scheduled storm recovery bond principal payments and $1.9 million for related interest payments, partially offset by collections of $5.2 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. On April 25, 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. On April 28, 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 March 31, 2017, $0.7 million of the charitable contributions and $124.7 million of the rate credits had been remitted 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 is currently scheduled to be submitted to the LPSC by June 30, 2017. There were no open natural gas positions at March 31, 2017, or December 31, 2016.

Cleco Power purchases the majority of its FTRs in annual auctions facilitated by MISO during the second quarter of each year and may also purchase additional FTRs in monthly auctions facilitated by MISO. 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 initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period 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 March 31, 2017, Cleco Power’s Condensed Consolidated Balance Sheets reflected the fair value of open FTR positions of $5.0 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 the successor period for the three months ended March 31, 2017, and for the predecessor period for the three months ended March 31, 2016, Cleco did not enter into any contracts to mitigate the volatility in interest rate risk. For the three months ended March 31, 2017, and 2016, Cleco Power 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, the ESPP and the LTIP 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 March 31, 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 March 31, 2016, Cleco reported pretax compensation expense of $1.0 million on non-vested stock with a related tax benefit of $0.4 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 three months ended March 31, 2016, Cleco Power reported pretax compensation expense of $0.4 million on non-vested stock with a related tax benefit of $0.1 million.

XML

Business Combination

3 Months Ended

Mar. 31, 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/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. In November and December 2016, Cleco Power redeemed $60.0 million and $250.0 million in long-term debt, respectively. As a result, the fair value adjustments for the redeemed long-term debt and the related unamortized debt issuance cost of $19.8 million on Cleco’s Consolidated Balance Sheet were derecognized. The offset was to the respective regulatory assets.

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 first quarter of 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

3 Months Ended

Mar. 31, 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 the ability to recognize revenue in situations where collectability is in question. Management will continue to evaluate the impact of this guidance, including additional clarifying amendments issued following the date of initial issuance. The amended guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants.

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. Early adoption is permitted. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes practical expedients that may be elected by entities. Management will continue to evaluate the impact of this guidance. The amended guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants.

In November 2016, FASB amended guidance for certain cash flow issues. The amended guidance requires that a statement of cash 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 reporting periods within those fiscal years. Early adoption is permitted. 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 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 is evaluating the impact that the adoption of this guidance will have 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 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 is currently evaluating the impact of this standard, including coordinating with its industry group as well as its advisors. The adoption of this guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants.

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Regulatory Assets and Liabilities

3 Months Ended

Mar. 31, 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 MAR. 31, 2017		AT DEC. 31, 2016
Regulatory assets – deferred taxes, net	$	238,378	$	237,449
Mining costs	5,735		6,372
Interest costs	4,770		4,860
AROs	2,252		2,096
Postretirement costs	142,873		145,268
Tree trimming costs	5,874		5,549
Training costs	6,669		6,708
Surcredits, net	5,028		5,876
AMI deferred revenue requirement	4,636		4,772
Production operations and maintenance expenses	12,551		13,999
AFUDC equity gross-up	70,185		70,423
Acadia Unit 1 acquisition costs	2,415		2,442
Financing costs	8,570		8,663
Biomass costs	11		18
MISO integration costs	1,170		1,404
Coughlin transaction costs	991		999
Corporate franchise tax	654		1,308
MATS costs	4,501		4,270
Other	591		710
Total regulatory assets	279,476		285,737
Fuel and purchased power	24,212		20,787
Total regulatory assets, net	$	542,066	$	543,973

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

(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Total Cleco Power regulatory assets, net (1)	$	542,066	$	543,973
Cleco Holdings’ Merger adjustments
Fair value of long-term debt	153,479		155,776
Postretirement costs	22,866		23,362
Financing costs	8,880		8,966
Debt issuance costs	6,975		7,606
Total Cleco regulatory assets, net	$	734,266	$	739,683

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

of the Merger.

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 will be 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 will be amortized over the terms of the related debt issuances. In November and December 2016, Cleco Power redeemed $60.0 million and $250.0 million in long-term debt, respectively. As a result, the fair value adjustments for the redeemed long-term debt and the related unamortized debt issuance cost of $19.8 million on Cleco’s Consolidated Balance Sheets were derecognized. The offset was to the respective regulatory assets.

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Fair Value Accounting

3 Months Ended

Mar. 31, 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 March 31, 2017, and December 31, 2016, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, and accounts payable approximate fair value because of their short-term nature.

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

Cleco
	AT MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,756,889	$	2,766,056	$	2,768,149	$	2,754,518

* The carrying value of long-term debt does not include deferred issuance costs of $11.7 million at March 31, 2017, and $11.7 million at December 31, 2016.

Cleco Power
	AT MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,253,410	$	1,418,027	$	1,262,373	$	1,418,693

* The carrying value of long-term debt does not include deferred issuance costs of $8.8 million at March 31, 2017, and $9.4 million at December 31, 2016.

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 MAR. 31, 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	$	56,624	$	—	$	56,624	$	—	$	66,410	$	—	$	66,410	$	—
FTRs	4,957		—		—		4,957		7,884		—		—		7,884
Total assets	$	61,581	$	—	$	56,624	$	4,957	$	74,294	$	—	$	66,410	$	7,884
Liability description
FTRs	539		—		—		539		201		—		—		201
Total liabilities	$	539	$	—	$	—	$	539	$	201	$	—	$	—	$	201

Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT MAR. 31, 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	$	56,598	$	—	$	56,598	$	—	$	65,089	$	—	$	65,089	$	—
FTRs	4,957		—		—		4,957		7,884		—		—		7,884
Total assets	$	61,555	$	—	$	56,598	$	4,957	$	72,973	$	—	$	65,089	$	7,884
Liability description
FTRs	539		—		—		539		201		—		—		201
Total liabilities	$	539	$	—	$	—	$	539	$	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 MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Beginning balance	$	7,683		$	7,398
Unrealized gains (losses)*	2,104			(832		)
Purchases	275			46
Settlements	(5,644		)	(4,746		)
Ending balance	$	4,418		$	1,866
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco’s Condensed Consolidated Balance Sheet.

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017			2016
Beginning balance	$	7,683		$	7,398
Unrealized gains (losses)*	2,104			(832		)
Purchases	275			46
Settlements	(5,644		)	(4,746		)
Ending balance	$	4,418		$	1,866
* 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 March 31, 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 Mar. 31, 2017	$	4,957	$	539	RTO auction pricing	FTR price - per MWh	$	(3.25	)	$	6.63
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. 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. Cleco has consistently applied the Level 2 fair value technique from fiscal period to fiscal period. 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 and therefore RTO auction prices are used. Significant increases or decreases in any of those inputs in isolation would result in a significantly different fair value measurement.

The assets and liabilities reported at fair value are grouped into classes based on the underlying nature and risks associated with the individual asset or liability.

At March 31, 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 $19.0 million, $14.1 million, and $23.5 million, respectively, at March 31, 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 $19.0 million, $14.1 million, and $23.5 million, respectively, at March 31, 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 three months ended March 31, 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 March 31, 2017, and December 31, 2016:

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT MAR. 31, 2017		AT DEC. 31, 2016
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	4,957	$	7,884
Current	Energy risk management liabilities	539		201
Commodity-related contracts, net		$	4,418	$	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 three months ended March 31, 2017, and 2016:

Cleco
	AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		SUCCESSOR			PREDECESSOR
(THOUSANDS)	DERIVATIVES LINE ITEM	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Commodity contracts
FTRs(1)	Electric operations	$	9,163		$	8,520
FTRs(1)	Power purchased for utility customers	(4,665		)	(5,723		)
Total		$	4,498		$	2,797

⁽¹⁾ For the period January 1, 2017 - March 31, 2017, unrealized gains associated with FTRs not recognized in income on derivatives of $2.1 million were reported through Accumulated deferred fuel on the balance sheet. For the period January 1, 2016 - March 31, 2016, unrealized losses associated with FTRs not recognized in income on derivatives of $0.8 million were reported through Accumulated deferred fuel on the balance sheet.

Cleco Power
	AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	DERIVATIVES LINE ITEM	2017			2016
Commodity contracts
FTRs(1)	Electric operations	$	9,163		$	8,520
FTRs(1)	Power purchased for utility customers	(4,665		)	(5,723		)
Total		$	4,498		$	2,797

⁽¹⁾ For the three months ended March 31, 2017, and 2016, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $2.1 million and ($0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

At March 31, 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 is currently scheduled to be submitted to the LPSC by June 30, 2017.

Cleco Power purchases the majority of its FTRs in annual auctions facilitated by MISO during the second quarter of each year and may also purchase additional FTRs in monthly auctions facilitated by MISO. 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 March 31, 2017, and December 31, 2016, was 3.6 million MWh and 9.0 million MWh, respectively.

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Debt

3 Months Ended

Mar. 31, 2017

Debt Disclosure [Abstract]

Debt

Note 6 — Debt

On May 17, 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% senior notes due May 1, 2026, and 4.973% senior notes due May 1, 2046, 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

3 Months Ended

Mar. 31, 2017

Compensation and Retirement Disclosure [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 months ended March 31, 2017, and 2016 are as follows:

	PENSION BENEFITS						OTHER BENEFITS
	SUCCESSOR			PREDECESSOR			SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016			FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Components of periodic benefit costs
Service cost	$	2,225		$	2,262		$	385		$	380
Interest cost	5,358			5,507			403			420
Expected return on plan assets	(6,138		)	(6,010		)	—			—
Amortizations
Prior period service (credit) cost	(18		)	(18		)	—			30
Net loss (gain)	2,413			2,469			(3		)	160
Net periodic benefit cost	$	3,840		$	4,210		$	785		$	990

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 successor period January 1, 2017, through March 31, 2017, was $0.4 million. The amount for the predecessor period for the three months ended March 31, 2016, was $0.4 million.

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 months ended March 31, 2017, was $0.9 million. The amount for the same period in 2016 was $0.8 million. The current and non-current portions of the other benefits liability for Cleco and Cleco Power at March 31, 2017, and December 31, 2016, are as follows:

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	3,854	$	3,854
Non-current	$	39,934	$	40,196

Cleco Power
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	3,345	$	3,345
Non-current	$	34,668	$	34,892

SERP

Certain Cleco officers are covered by SERP. 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 limits of the 401(k) Plan. Two 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. 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 above. 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. 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 designated as the beneficiary for life insurance policies issued on SERP participants. 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 months ended March 31, 2017, and 2016 are as follows:

	SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Components of periodic benefit costs
Service cost	$	145		$	583
Interest cost	800			731
Amortizations
Prior period service (credit) cost	(57		)	13
Net loss	419			655
Net periodic benefit cost	1,307			1,982
Special/contractual termination benefits	315			—
Total benefit cost	$	1,622		$	1,982

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 special termination benefits of $0.3 million.

The total expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income was $0.3 million for the three months ended March 31, 2017, compared to $0.4 million for the same period in 2016.

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

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	4,308	$	4,308
Non-current	$	77,329	$	73,738

Cleco Power
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	885	$	885
Non-current	$	16,075	$	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 can be made in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Prior to the close of the Merger on April 13, 2016, employer contributions could also be in the form of Cleco Corporation common stock. 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 monthsended March 31, 2017, and 2016 is as follows:

	SUCCESSOR		PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
401(k) Plan expense	$	1,668	$	1,374

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three months ended March 31, 2017, and 2016 is as follows:

	SUCCESSOR		PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
401(k) Plan expense	$	279	$	282

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Income Taxes

3 Months Ended

Mar. 31, 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 months ended March 31, 2017, and 2016:

Cleco
	SUCCESSOR		PREDECESSOR
	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
Effective tax rate	33.1	%	38.5	%

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31,
	2017		2016
Effective tax rate	35.6	%	37.6	%

For the successor period, the effective income tax rate for Cleco was 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 rate for Cleco was 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 months ended March 31, 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.

Valuation Allowance

Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a tax benefit will not be realized. As of March 31, 2017, and December 31, 2016, Cleco had a deferred tax asset resulting from NMTC carryforwards of $97.5 million. If the NMTC carryforwards are not utilized, they will begin to expire in 2029. Management considers it more likely than not that all deferred tax assets related to NMTC carryforwards will be realized; therefore, no valuation allowance has been recorded.

Net Operating Losses

As of March 31, 2017, Cleco has a federal net operating loss carryforward of $82.1 million and a state net operating loss carryforward of $193.1 million. The federal and state net operating loss carryforwards will begin to expire in 2031. Cleco considers it more likely than not that these income tax losses will be utilized to reduce future income tax payments and Cleco expects to utilize the entire net operating loss carryforward within the statutory deadlines.

Uncertain Tax Positions

Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. At March 31, 2017, and December 31, 2016, Cleco and Cleco Power had no interest payable related to uncertain tax positions. For the three months ended March 31, 2017, and 2016, Cleco and Cleco Power had no interest expense related to uncertain tax positions.

At March 31, 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 March 31, 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, and 2015. The IRS has concluded its audit for the years 2010 through 2014.

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 three months ended March 31, 2017, and 2016, no penalties were recognized.

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Disclosures about Segments

3 Months Ended

Mar. 31, 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 provided by Support Group.

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MAR. 31,
	SUCCESSOR
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	237,553		$	(3,497	)	$	—		$	234,056
Other operations	16,365			515			—			16,880
Electric customer credits	(435		)	—			—			(435		)
Affiliate revenue	219			14,734			(14,953		)	—
Operating revenue, net	$	253,702		$	11,752		$	(14,953	)	$	250,501
Depreciation and amortization	$	38,758		$	2,093		$	—		$	40,851
Merger transaction and commitment costs	$	—		$	99		$	—		$	99
Interest charges	$	18,104		$	13,681		$	(67	)	$	31,718
Interest income	$	266		$	113		$	(67	)	$	312
Federal and state income tax expense (benefit)	$	9,855		$	(6,748	)	$	—		$	3,107
Net income (loss)	$	17,854		$	(11,562	)	$	—		$	6,292
Additions to property, plant, and equipment	$	46,744		$	1,146		$	—		$	47,890
Equity investment in investees	$	18,672		$	—		$	—		$	18,672
Goodwill	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets	$	5,748,503		$	621,406		$	(33,928	)	$	6,335,981

	PREDECESSOR
2016 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	250,157		$	—		$	—		$	250,157
Other operations	16,614			518			—			17,132
Electric customer credits	(321		)	—			—			(321		)
Affiliate revenue	232			13,024			(13,256		)	—
Operating revenue, net	$	266,682		$	13,542		$	(13,256	)	$	266,968
Depreciation and amortization	$	38,603		$	335		$	—		$	38,938
Merger transaction costs	$	—		$	1,539		$	(17	)	$	1,522
Interest charges	$	19,285		$	278		$	(10	)	$	19,553
Interest income	$	179		$	55		$	(10	)	$	224
Federal and state income tax expense (benefit)	$	12,563		$	(426	)	$	—		$	12,137
Net income (loss)	$	20,879		$	(1,511	)	$	—		$	19,368
Additions to property, plant, and equipment	$	35,453		$	23		$	—		$	35,476
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 (Successor)

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Regulation and Rates

3 Months Ended

Mar. 31, 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, is for the period November 2013 through February 2015. On September 29, 2016, FERC issued a Final Order in response to the first complaint establishing a 10.32% ROE.

The second complaint, filed in February 2015, is 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 ofMarch 31, 2017, Cleco Power had$1.9 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 must file annual monitoring reports no later than October 31 for the 12-month period ended June 30. Cleco Power was scheduled to file an application with the LPSC for a new FRP by June 30, 2017. However, as part of the merger approval process Cleco Power agreed not to file an application for a new FRP or request an increase in base rates until June 30, 2019, with anticipated new rates being effective July 1, 2020.

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 May 1, 2017, the LPSC filed the report of its review of the 2016 FRP monitoring report which confirmed no earnings-related refunds. The report is expected to be approved in June 2017. For more information on Merger Commitments, see “— Merger Commitments.”

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 March 31, 2017, Cleco Power had issued $125.0 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 or another state agency, 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 savings are not subject to the target ROE or any sharing mechanism in the current FRP and will continue until Cleco Power files for a new FRP in 2019. The cost savings will be refunded to customers annually beginning in September 2017. As of March 31, 2017, Cleco Power had $1.2 million accrued for the cost savings refund. 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.

Other

On April 8, 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. On April 8, 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. On October 4, 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 anticipates the completion of this agreement in the second half of 2017.

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Variable Interest Entities

3 Months Ended

Mar. 31, 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 March 31, 2017, consisted of its equity investment of $18.7 million.

During the first quarter of 2017, the transition from the Dolet Hills mine to the Oxbow mine commenced. This transition is expected to be completed in the third quarter of 2017.

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

INCEPTION TO DATE (THOUSANDS)	AT MAR. 31, 2017			AT DEC. 31, 2016
Purchase price	$	12,873		$	12,873
Cash contributions	6,399			6,399
Dividend received	(600		)	(600		)
Total equity investment in investee	$	18,672		$	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 MAR. 31, 2017		AT DEC. 31, 2016
Oxbow’s net assets/liabilities	$	37,345	$	37,345
Cleco Power’s 50% equity	$	18,672	$	18,672
Cleco Power’s maximum exposure to loss	$	18,672	$	18,672

The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017		2016
Operating revenue	$	1,073	$	2,101
Operating expenses	1,073		2,101
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

3 Months Ended

Mar. 31, 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. 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.

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 on November 9, 2016. The Third Circuit Court of Appeal issued a schedule requiring plaintiffs to file their brief on April 18, 2017, with Cleco’s brief due on May 4, 2017. The plaintiffs have requested an extension of the briefing schedule. Cleco anticipates the plaintiffs’ brief will be due on May 18, 2017, with Cleco’s brief being due on June 7, 2017, pending any requests for extension.

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. On January 21, 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. On June 30, 2016, the Third Circuit Court of Appeal for the State of Louisiana denied the request to have the case dismissed. On July 29, 2016, Cleco filed a writ to the Louisiana Supreme Court seeking a review of the District Court’s denial of Cleco’s exception. On November 15, 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. On May 16, 2016, the District Court lifted the stay at the request of Gulf Coast. 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.

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

LPSC Audits

Fuel Audit

Generally, the cost of fuel used for electric generation and the cost of power purchased for utility customers are recovered through the LPSC-established FAC that enables Cleco Power to pass on to its customers substantially all such charges. Recovery of FAC costs is subject to periodic fuel audits by the LPSC. The LPSC FAC General Order issued in November 1997, in Docket No. U-21497 provides that an audit of FAC filings will be performed at least every other year. On February 3, 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. On February 3, 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 this audit was $81.2 million. On December 1, 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.

Cleco Power began incurring additional environmental compliance expenses in the second quarter of 2015 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. On April 15, 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. 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, is for the period November 2013 through February 2015. On September 29, 2016, FERC issued a Final Order in response to the first complaint establishing a 10.32% ROE.

In February 2015, a second ROE complaint was filed 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 March 31, 2017, Cleco Power had $1.9 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 March 31, 2017, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters is $4.8 million and has accrued this amount.

Off-Balance Sheet Commitments and Guarantees

Cleco Holdings and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and 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 these 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. At March 31, 2017, 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. At March 31, 2017, 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 on Cleco’s Condensed Consolidated Balance Sheet in the line item Tax credit fund investment, net. 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 March 31, 2017, was $18.1 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.

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 8, 2016, taking into consideration the anticipated completion of the Merger, S&P and Moody’s downgraded Cleco Holdings’ credit ratings to BBB- (stable) and Baa3 (stable), respectively. On April 8, 2016, taking into consideration the anticipated completion of the Merger, S&P and Moody’s credit ratings were maintained at Cleco Power at BBB+ (stable) and A3 (stable), respectively. On April 7, 2017, Moody’s updated its credit ratings by maintaining Cleco Holdings at Baa3 (stable) and Cleco Power at A3 (stable).

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

3 Months Ended

Mar. 31, 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 MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	1	$	176	$	3	$	119
Support Group	1,377		9,191		1,402		7,071
Other (1)	—		—		1		—
Total	$	1,378	$	9,367	$	1,406	$	7,190
(1) Represents Attala and Perryville.

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Accumulated Other Comprehensive Loss

3 Months Ended

Mar. 31, 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 MAR. 31, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
SUCCESSOR
Balances, beginning of period	$	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 loss	(126		)	—		(126		)
Net current-period other comprehensive loss	(2,191		)	—		(2,191		)
Balances, Mar. 31, 2017	$	(691	)	$	—	$	(691	)

	FOR THE THREE MONTHS ENDED MAR. 31, 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	528			—			528
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive income	528			53			581
Balances, Mar. 31, 2016	$	(20,329	)	$	(5,675	)	$	(26,004	)

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive income before reclassifications
Postretirement benefit adjustments during the period	(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	164			—			164
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive (loss) income	(420		)	53			(367		)
Balances, Mar. 31, 2017	$	(8,325	)	$	(5,464	)	$	(13,789	)

	FOR THE THREE MONTHS ENDED MAR. 31, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(11,364	)	$	(5,728	)	$	(17,092	)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	200			—			200
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive income	200			53			253
Balances, Mar. 31, 2016	$	(11,164	)	$	(5,675	)	$	(16,839	)

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Summary of Significant Accounting Policies (Policies)

3 Months Ended

Mar. 31, 2017

Accounting Policies [Abstract]

Principles of Consolidation, Policy

The accompanying Condensed Consolidated Financial Statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Basis of Presentation, 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.

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. 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. Cleco has consistently applied the Level 2 fair value technique from fiscal period to fiscal period. 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 and therefore RTO auction prices are used. 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 the majority of its FTRs in annual auctions facilitated by MISO during the second quarter of each year and may also purchase additional FTRs in monthly auctions facilitated by MISO. 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 initially records FTRs at their estimated fair value and subsequently adjusts the carrying value to their estimated fair value at the end of each accounting period 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.

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.

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 is currently scheduled to be submitted to the LPSC by June 30, 2017

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, the ESPP and the LTIP 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/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. In November and December 2016, Cleco Power redeemed $60.0 million and $250.0 million in long-term debt, respectively. As a result, the fair value adjustments for the redeemed long-term debt and the related unamortized debt issuance cost of $19.8 million on Cleco’s Consolidated Balance Sheet were derecognized. The offset was to the respective regulatory assets.

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 first quarter of 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 will be 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 will be 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 the ability to recognize revenue in situations where collectability is in question. Management will continue to evaluate the impact of this guidance, including additional clarifying amendments issued following the date of initial issuance. The amended guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants.

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. Early adoption is permitted. In transition, lessees and lessors are required to recognize and measure leases at the beginning of the earliest period presented using a modified retrospective approach. The modified retrospective approach includes practical expedients that may be elected by entities. Management will continue to evaluate the impact of this guidance. The amended guidance could have a material impact on the results of operations, financial condition, or cash flows of the Registrants.

In November 2016, FASB amended guidance for certain cash flow issues. The amended guidance requires that a statement of cash 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 reporting periods within those fiscal years. Early adoption is permitted. 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 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 is evaluating the impact that the adoption of this guidance will have 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 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 is currently evaluating the impact of this standard, including coordinating with its industry group as well as its advisors. The adoption of this guidance could have a material 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 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.

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’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 can be made in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Prior to the close of the Merger on April 13, 2016, employer contributions could also be in the form of Cleco Corporation common stock. Participation in the 401(k) Plan is voluntary, and all active Cleco employees are eligible to participate.

Certain Cleco officers are covered by SERP. 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 limits of the 401(k) Plan. Two 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. 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 above. 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. 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 designated as the beneficiary for life insurance policies issued on SERP participants. 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.

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.

Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a tax benefit will not be realized.

Segment Reporting, Policy

The financial results of Cleco’s segment are presented on an accrual basis.

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)

3 Months Ended

Mar. 31, 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 MAR. 31, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,432	$	9,213
Cleco Power’s charitable contributions	1,200		1,200
Cleco Power’s rate credit escrow	9,518		12,671
Total current	14,150		23,084
Non-current
Diversified Lands’ mitigation escrow	21		21
Cleco Power’s future storm restoration costs	17,576		17,379
Cleco Power’s charitable contributions	4,126		4,179
Cleco Power’s rate credit escrow	1,831		1,831
Total non-current	23,554		23,410
Total restricted cash and cash equivalents	$	37,704	$	46,494

Cleco Power [Member]

Accounting Policies [Line Items]

Restricted Cash and Cash Equivalents

Cleco Power
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current
Cleco Katrina/Rita’s storm recovery bonds	$	3,432	$	9,213
Charitable contributions	1,200		1,200
Rate credit escrow	9,518		12,671
Total current	14,150		23,084
Non-current
Future storm restoration costs	17,576		17,379
Charitable contributions	4,126		4,179
Rate credit escrow	1,831		1,831
Total non-current	23,533		23,389
Total restricted cash and cash equivalents	$	37,683	$	46,473

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Business Combination (Tables)

3 Months Ended

Mar. 31, 2017

Business Combinations [Abstract]

Schedule of Business Acquisitions, by Acquisition [Table Text Block]

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

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

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Regulatory Assets and Liabilities (Tables)

3 Months Ended

Mar. 31, 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 MAR. 31, 2017		AT DEC. 31, 2016
Total Cleco Power regulatory assets, net (1)	$	542,066	$	543,973
Cleco Holdings’ Merger adjustments
Fair value of long-term debt	153,479		155,776
Postretirement costs	22,866		23,362
Financing costs	8,880		8,966
Debt issuance costs	6,975		7,606
Total Cleco regulatory assets, net	$	734,266	$	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 MAR. 31, 2017		AT DEC. 31, 2016
Regulatory assets – deferred taxes, net	$	238,378	$	237,449
Mining costs	5,735		6,372
Interest costs	4,770		4,860
AROs	2,252		2,096
Postretirement costs	142,873		145,268
Tree trimming costs	5,874		5,549
Training costs	6,669		6,708
Surcredits, net	5,028		5,876
AMI deferred revenue requirement	4,636		4,772
Production operations and maintenance expenses	12,551		13,999
AFUDC equity gross-up	70,185		70,423
Acadia Unit 1 acquisition costs	2,415		2,442
Financing costs	8,570		8,663
Biomass costs	11		18
MISO integration costs	1,170		1,404
Coughlin transaction costs	991		999
Corporate franchise tax	654		1,308
MATS costs	4,501		4,270
Other	591		710
Total regulatory assets	279,476		285,737
Fuel and purchased power	24,212		20,787
Total regulatory assets, net	$	542,066	$	543,973

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Fair Value Accounting (Tables)

3 Months Ended

Mar. 31, 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 MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	2,756,889	$	2,766,056	$	2,768,149	$	2,754,518

* The carrying value of long-term debt does not include deferred issuance costs of $11.7 million at March 31, 2017, and $11.7 million at December 31, 2016

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 MAR. 31, 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	$	56,624	$	—	$	56,624	$	—	$	66,410	$	—	$	66,410	$	—
FTRs	4,957		—		—		4,957		7,884		—		—		7,884
Total assets	$	61,581	$	—	$	56,624	$	4,957	$	74,294	$	—	$	66,410	$	7,884
Liability description
FTRs	539		—		—		539		201		—		—		201
Total liabilities	$	539	$	—	$	—	$	539	$	201	$	—	$	—	$	201

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]

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 MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Beginning balance	$	7,683		$	7,398
Unrealized gains (losses)*	2,104			(832		)
Purchases	275			46
Settlements	(5,644		)	(4,746		)
Ending balance	$	4,418		$	1,866
* 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 [Table Text Block]

The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions as of March 31, 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 Mar. 31, 2017	$	4,957	$	539	RTO auction pricing	FTR price - per MWh	$	(3.25	)	$	6.63
FTRs at Dec. 31, 2016	$	7,884	$	201	RTO auction pricing	FTR price - per MWh	$	(3.61	)	$	6.04

Cleco Power [Member]

Fair Value [Line Items]

Fair Value By Balance Sheet Grouping

Cleco Power
	AT MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	CARRYING VALUE*		FAIR VALUE		CARRYING VALUE*		FAIR VALUE
Long-term debt	$	1,253,410	$	1,418,027	$	1,262,373	$	1,418,693

* The carrying value of long-term debt does not include deferred issuance costs of $8.8 million at March 31, 2017, and $9.4 million at December 31, 2016.

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 MAR. 31, 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	$	56,598	$	—	$	56,598	$	—	$	65,089	$	—	$	65,089	$	—
FTRs	4,957		—		—		4,957		7,884		—		—		7,884
Total assets	$	61,555	$	—	$	56,598	$	4,957	$	72,973	$	—	$	65,089	$	7,884
Liability description
FTRs	539		—		—		539		201		—		—		201
Total liabilities	$	539	$	—	$	—	$	539	$	201	$	—	$	—	$	201

Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017			2016
Beginning balance	$	7,683		$	7,398
Unrealized gains (losses)*	2,104			(832		)
Purchases	275			46
Settlements	(5,644		)	(4,746		)
Ending balance	$	4,418		$	1,866
* Unrealized gains and losses are reported through Accumulated deferred fuel on Cleco Power’s Condensed Consolidated Balance Sheet.

Derivatives Not Designated As Hedging Instrument [Member]

Fair Value [Line Items]

Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]

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

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM	AT MAR. 31, 2017		AT DEC. 31, 2016
Commodity-related contracts
FTRs
Current	Energy risk management assets	$	4,957	$	7,884
Current	Energy risk management liabilities	539		201
Commodity-related contracts, net		$	4,418	$	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 three months ended March 31, 2017, and 2016:

Cleco
	AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES
		SUCCESSOR			PREDECESSOR
(THOUSANDS)	DERIVATIVES LINE ITEM	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Commodity contracts
FTRs(1)	Electric operations	$	9,163		$	8,520
FTRs(1)	Power purchased for utility customers	(4,665		)	(5,723		)
Total		$	4,498		$	2,797

⁽¹⁾ For the period January 1, 2017 - March 31, 2017, unrealized gains associated with FTRs not recognized in income on derivatives of $2.1 million were reported through Accumulated deferred fuel on the balance sheet. For the period January 1, 2016 - March 31, 2016, unrealized losses associated with FTRs not recognized in income on derivatives of $0.8 million were reported through Accumulated deferred fuel on the balance sheet.

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

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 MAR. 31,
(THOUSANDS)	DERIVATIVES LINE ITEM	2017			2016
Commodity contracts
FTRs(1)	Electric operations	$	9,163		$	8,520
FTRs(1)	Power purchased for utility customers	(4,665		)	(5,723		)
Total		$	4,498		$	2,797

⁽¹⁾ For the three months ended March 31, 2017, and 2016, unrealized gains (losses) associated with FTRs not recognized in income on derivatives of $2.1 million and ($0.8) million, respectively, were reported through Accumulated deferred fuel on the balance sheet.

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Pension Plan and Employee Benefits (Tables)

3 Months Ended

Mar. 31, 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 months ended March 31, 2017, and 2016 are as follows:

	PENSION BENEFITS						OTHER BENEFITS
	SUCCESSOR			PREDECESSOR			SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016			FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Components of periodic benefit costs
Service cost	$	2,225		$	2,262		$	385		$	380
Interest cost	5,358			5,507			403			420
Expected return on plan assets	(6,138		)	(6,010		)	—			—
Amortizations
Prior period service (credit) cost	(18		)	(18		)	—			30
Net loss (gain)	2,413			2,469			(3		)	160
Net periodic benefit cost	$	3,840		$	4,210		$	785		$	990

401(k) Plan expense

Cleco’s 401(k) Plan expense for the three monthsended March 31, 2017, and 2016 is as follows:

	SUCCESSOR		PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
401(k) Plan expense	$	1,668	$	1,374

Other Benefits [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 March 31, 2017, and December 31, 2016, are as follows:

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	3,854	$	3,854
Non-current	$	39,934	$	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 months ended March 31, 2017, and 2016 are as follows:

	SUCCESSOR			PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017			FOR THE THREE MONTHS ENDED MAR. 31, 2016
Components of periodic benefit costs
Service cost	$	145		$	583
Interest cost	800			731
Amortizations
Prior period service (credit) cost	(57		)	13
Net loss	419			655
Net periodic benefit cost	1,307			1,982
Special/contractual termination benefits	315			—
Total benefit cost	$	1,622		$	1,982

Schedule of current and non-current portions

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

Cleco
(THOUSANDS)	AT MAR. 31, 2017		AT DEC. 31, 2016
Current	$	4,308	$	4,308
Non-current	$	77,329	$	73,738

Cleco Power [Member] | Other 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 MAR. 31, 2017		AT DEC. 31, 2016
Current	$	3,345	$	3,345
Non-current	$	34,668	$	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 MAR. 31, 2017		AT DEC. 31, 2016
Current	$	885	$	885
Non-current	$	16,075	$	15,145

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 months ended March 31, 2017, and 2016 is as follows:

	SUCCESSOR		PREDECESSOR
(THOUSANDS)	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
401(k) Plan expense	$	279	$	282

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Income Taxes (Tables)

3 Months Ended

Mar. 31, 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 months ended March 31, 2017, and 2016:

Cleco
	SUCCESSOR		PREDECESSOR
	FOR THE THREE MONTHS ENDED MAR. 31, 2017		FOR THE THREE MONTHS ENDED MAR. 31, 2016
Effective tax rate	33.1	%	38.5	%

Cleco Power [Member]

Effective Income Tax Rate [Line Items]

Effective income tax rates

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31,
	2017		2016
Effective tax rate	35.6	%	37.6	%

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Disclosures about Segments (Tables)

3 Months Ended

Mar. 31, 2017

Segment Reporting [Abstract]

Segment Information

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MAR. 31,
	SUCCESSOR
2017 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	237,553		$	(3,497	)	$	—		$	234,056
Other operations	16,365			515			—			16,880
Electric customer credits	(435		)	—			—			(435		)
Affiliate revenue	219			14,734			(14,953		)	—
Operating revenue, net	$	253,702		$	11,752		$	(14,953	)	$	250,501
Depreciation and amortization	$	38,758		$	2,093		$	—		$	40,851
Merger transaction and commitment costs	$	—		$	99		$	—		$	99
Interest charges	$	18,104		$	13,681		$	(67	)	$	31,718
Interest income	$	266		$	113		$	(67	)	$	312
Federal and state income tax expense (benefit)	$	9,855		$	(6,748	)	$	—		$	3,107
Net income (loss)	$	17,854		$	(11,562	)	$	—		$	6,292
Additions to property, plant, and equipment	$	46,744		$	1,146		$	—		$	47,890
Equity investment in investees	$	18,672		$	—		$	—		$	18,672
Goodwill	$	1,490,797		$	—		$	—		$	1,490,797
Total segment assets	$	5,748,503		$	621,406		$	(33,928	)	$	6,335,981

	PREDECESSOR
2016 (THOUSANDS)	CLECO POWER			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	250,157		$	—		$	—		$	250,157
Other operations	16,614			518			—			17,132
Electric customer credits	(321		)	—			—			(321		)
Affiliate revenue	232			13,024			(13,256		)	—
Operating revenue, net	$	266,682		$	13,542		$	(13,256	)	$	266,968
Depreciation and amortization	$	38,603		$	335		$	—		$	38,938
Merger transaction costs	$	—		$	1,539		$	(17	)	$	1,522
Interest charges	$	19,285		$	278		$	(10	)	$	19,553
Interest income	$	179		$	55		$	(10	)	$	224
Federal and state income tax expense (benefit)	$	12,563		$	(426	)	$	—		$	12,137
Net income (loss)	$	20,879		$	(1,511	)	$	—		$	19,368
Additions to property, plant, and equipment	$	35,453		$	23		$	—		$	35,476
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 (Successor)

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

3 Months Ended

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

Equity Method Investments

The following table contains summarized financial information for Oxbow:

	FOR THE THREE MONTHS ENDED MAR. 31,
(THOUSANDS)	2017		2016
Operating revenue	$	1,073	$	2,101
Operating expenses	1,073		2,101
Income before taxes	$	—	$	—

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

INCEPTION TO DATE (THOUSANDS)	AT MAR. 31, 2017			AT DEC. 31, 2016
Purchase price	$	12,873		$	12,873
Cash contributions	6,399			6,399
Dividend received	(600		)	(600		)
Total equity investment in investee	$	18,672		$	18,672

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Affiliate Transactions (Tables)

3 Months Ended

Mar. 31, 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 MAR. 31, 2017				AT DEC. 31, 2016
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Holdings	$	1	$	176	$	3	$	119
Support Group	1,377		9,191		1,402		7,071
Other (1)	—		—		1		—
Total	$	1,378	$	9,367	$	1,406	$	7,190
(1) Represents Attala and Perryville.

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Accumulated Other Comprehensive Loss (Tables)

3 Months Ended

Mar. 31, 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 MAR. 31, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES		TOTAL AOCI
SUCCESSOR
Balances, beginning of period	$	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 loss	(126		)	—		(126		)
Net current-period other comprehensive loss	(2,191		)	—		(2,191		)
Balances, Mar. 31, 2017	$	(691	)	$	—	$	(691	)

	FOR THE THREE MONTHS ENDED MAR. 31, 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	528			—			528
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive income	528			53			581
Balances, Mar. 31, 2016	$	(20,329	)	$	(5,675	)	$	(26,004	)

Cleco Power [Member]

Accumulated Other Comprehensive Loss [Line Items]

Schedule of Accumulated Other Comprehensive Income (Loss)

Cleco Power
	FOR THE THREE MONTHS ENDED MAR. 31, 2017
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(7,905	)	$	(5,517	)	$	(13,422	)
Other comprehensive income before reclassifications
Postretirement benefit adjustments during the period	(584		)	—			(584		)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	164			—			164
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive (loss) income	(420		)	53			(367		)
Balances, Mar. 31, 2017	$	(8,325	)	$	(5,464	)	$	(13,789	)

	FOR THE THREE MONTHS ENDED MAR. 31, 2016
(THOUSANDS)	POSTRETIREMENT BENEFIT NET LOSS			NET LOSS ON CASH FLOW HEDGES			TOTAL AOCI
Balances, beginning of period	$	(11,364	)	$	(5,728	)	$	(17,092	)
Amounts reclassified from accumulated other comprehensive income
Amortization of postretirement benefit net loss	200			—			200
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive income	200			53			253
Balances, Mar. 31, 2016	$	(11,164	)	$	(5,675	)	$	(16,839	)

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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

XML

Summary of Significant Accounting Policies, Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016	Apr. 25, 2016
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	$ 14,150		$ 23,084
Total non-current	23,554		23,410
Total restricted cash and cash equivalents	37,704		46,494
Cleco Katrina Rita Storm Recovery Bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	3,432		9,213
Cleco Power's charitable contributions [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	1,200		1,200
Total non-current	4,126		4,179
Cleco Power's rate credit escrow [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	9,518		12,671
Total non-current	1,831		1,831
Diversified Lands’ mitigation escrow
Restricted Cash and Cash Equivalents Items [Line Items]
Total non-current	21		21
Cleco Power’s future storm restoration costs
Restricted Cash and Cash Equivalents Items [Line Items]
Total non-current	17,576		17,379
Katrina Rita storm recovery collections, net of administration fees
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (Decrease) in Restricted Cash	5,200
Katrina Rita Bond Principal Payments
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (Decrease) in Restricted Cash	(9,100)
Katrina Rita Bond Interest Payments [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Increase (Decrease) in Restricted Cash	(1,900)
Cleco Power [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	14,150		23,084
Total non-current	23,533		23,389
Total restricted cash and cash equivalents	37,683		46,473
Increase (Decrease) in Restricted Cash	(8,790)	$ (4,088)
Cleco Power [Member] | Cleco Katrina Rita Storm Recovery Bonds
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	3,432		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
Total non-current	4,126		4,179
Total restricted cash and cash equivalents				$ 6,000
Increase (Decrease) in Restricted Cash	(700)
Cleco Power [Member] | Cleco Power's rate credit escrow [Member]
Restricted Cash and Cash Equivalents Items [Line Items]
Total current	9,518		12,671
Total non-current	1,831		1,831
Total restricted cash and cash equivalents				$ 136,000
Increase (Decrease) in Restricted Cash	(124,700)
Cleco Power [Member] | Cleco Power’s future storm restoration costs
Restricted Cash and Cash Equivalents Items [Line Items]
Total non-current	$ 17,576		$ 17,379

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Summary of Significant Accounting Policies, Risk Management (Details) $ in Millions	Mar. 31, 2017 USD ($) contract MMBTU	Dec. 31, 2016 USD ($) MMBTU	Mar. 31, 2016 contract
Other Current Assets [Member] | Cleco Power [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
FTRs in Energy risk management asset | $	$ 5.0	$ 7.9
Other Current Liabilities [Member] | Cleco Power [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
FTRs in Energy risk management liability | $	$ 0.5	$ 0.2
Open Natural Gas Positions [Member] | Cleco Power [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk | MMBTU	0	0
Interest Rate Contract [Member] | Cleco Power [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk	0		0
Successor [Member] | Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk	0
Predecessor [Member] | Interest Rate Contract [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of instruments held to mitigate risk			0

XML

Summary of Significant Accounting Policies, Stock-Based Compensation (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended
	Apr. 30, 2016	Mar. 31, 2016
Cleco Power [Member]
Stock-Based Compensation [Line Items]
Tax benefit		$ 0.1
Cleco Power [Member] | Non-vested Stock [Member]
Stock-Based Compensation [Line Items]
Non-vested stock		0.4
Predecessor [Member]
Stock-Based Compensation [Line Items]
Tax benefit		0.4
Predecessor [Member] | Non-vested Stock [Member]
Stock-Based Compensation [Line Items]
Non-vested stock		$ 1.0
Share-based Compensation Arrangement by Share-based Payment Award, Additional General Disclosures [Abstract]
Non-vested stock granted during the period pursuant to the LTIP (in shares)		0
Merger expense due to accelerated vesting of the LTIP shares	$ 2.3

XML

Business Combination (Details) - USD ($)		1 Months Ended		2 Months Ended	3 Months Ended
	Apr. 13, 2016	Dec. 31, 2016	Nov. 30, 2016	Dec. 31, 2016	Mar. 31, 2017	Apr. 07, 2016
Business Acquisition [Line Items]
Accumulated depreciation	$ 0	$ 75,816,000		$ 75,816,000	$ 98,969,000
Deferred tax liabilities recognized for goodwill	0
Derecognized fair value adjustment and debt issuance costs related to debt redemption				19,800,000
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	$ 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
Cleco Trade Name [Member]
Business Acquisition [Line Items]
Trade name intangible asset, useful life					20 years
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
Accumulated Deferred Federal and State Income Taxes [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
Non-vested Stock [Member]
Business Acquisition [Line Items]
Remaining LTIP equity awards at close of Merger	0
Merger Commitments, rate credits [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments						$ 136,000,000
Merger Commitments, economic development contribution [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments						7,000,000
Merger Commitments, charitable contribution, disbursed over 5 years [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments						6,000,000
Merger Commitments, economic development contribution, disbursed over 5 years [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments						2,500,000
Merger Commitments, cost savings [Member] | LPSC [Member]
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		1,618,241,000		1,618,241,000	$ 1,634,875,000
Cleco Power [Member] | Cleco Power's solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016 [Member] | Unsecured Debt [Member]
Business Acquisition [Line Items]
Redeemed long term debt			$ 60,000,000
Cleco Power [Member] | Cleco Power's senior notes, 6.65%, due 2018 [Member] | Unsecured Debt [Member]
Business Acquisition [Line Items]
Redeemed long term debt		250,000,000
Cleco Power [Member] | Merger Commitments, rate credits [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments						136,000,000
Cleco Power [Member] | Merger Commitments, economic development contribution [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments		$ 7,000,000		$ 7,000,000		7,000,000
Cleco Power [Member] | Merger Commitments, charitable contribution, disbursed over 5 years [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments						6,000,000
Cleco Power [Member] | Merger Commitments, economic development contribution, disbursed over 5 years [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments						2,500,000
Cleco Power [Member] | Merger Commitments, cost savings [Member] | LPSC [Member]
Business Acquisition [Line Items]
Merger Commitments						$ 1,200,000

XML

Regulatory Assets and Liabilities, Summary of Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Total regulatory assets, net	$ 734,266	$ 739,683
Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	279,476	285,737
Total regulatory assets, net	542,066	543,973
Regulatory assets – deferred taxes, net | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	238,378	237,449
Mining costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	5,735	6,372
Interest costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,770	4,860
AROs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,252	2,096
Postretirement costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	22,866	23,362
Postretirement costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	142,873	145,268
Tree trimming costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	5,874	5,549
Training costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	6,669	6,708
Surcredits, net | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	5,028	5,876
AMI deferred revenue requirement | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,636	4,772
Production operations and maintenance expenses | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	12,551	13,999
AFUDC equity gross-up | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	70,185	70,423
Acquisition/ transaction costs [Member] | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	2,415	2,442
Acquisition/ transaction costs [Member] | Coughlin transaction costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	991	999
Financing costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,880	8,966
Financing costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	8,570	8,663
Biomass costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	11	18
MISO integration costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	1,170	1,404
Corporate franchise tax | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	654	1,308
MATS costs | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	4,501	4,270
Other | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	591	710
Fuel and purchased power | Cleco Power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	24,212	20,787
Fair value of long-term debt
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	153,479	155,776
Debt issuance costs
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets	$ 6,975	$ 7,606

XML

Regulatory Assets and Liabilities, Additional Disclosures (Details) - USD ($) $ in Millions	1 Months Ended		2 Months Ended
	Dec. 31, 2016	Nov. 30, 2016	Dec. 31, 2016
Regulatory Assets [Line Items]
Derecognized fair value adjustment and debt issuance costs related to debt redemption			$ 19.8
Unsecured Debt [Member] | Cleco Power's solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016 [Member] | Cleco Power [Member]
Regulatory Assets [Line Items]
Extinguishment of Debt, Amount		$ 60.0
Unsecured Debt [Member] | Cleco Power's senior notes, 6.65%, due 2018 [Member] | Cleco Power [Member]
Regulatory Assets [Line Items]
Extinguishment of Debt, Amount	$ 250.0

XML

Fair Value Accounting, Carrying Value and Estimated Fair Value (Details) - USD ($) $ in Thousands	Mar. 31, 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	$ 11,700	$ 11,700
Estimated Fair Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt	2,766,056	2,754,518
Carrying Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt	2,756,889	2,768,149
Cleco Power [Member]
Financial instruments not marked-to-market [Abstract]
Deferred debt issuance costs not included in the carrying value of long-term debt	8,800	9,400
Cleco Power [Member] | Estimated Fair Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt	1,418,027	1,418,693
Cleco Power [Member] | Carrying Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt	$ 1,253,410	$ 1,262,373

XML

Fair Value Accounting, Fair Value Measurements and Disclosures(Details)	3 Months Ended
	Mar. 31, 2017 USD ($) $ / MW	Mar. 31, 2016 USD ($)	Dec. 31, 2016 USD ($) $ / MW
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
FTR Forward Price - per MWh, Low | $ / MW	(3.25)		(3.61)
FTRs Forward Price - per MWh, High | $ / MW	6.63		6.04
Fair Value, Concentration of Risk, Amount of Money Market Funds in Cash and Cash Equivalents	$ 19,000,000		$ 20,000,000
Fair Value, Assets and Liabilities, Transfers between Levels, Amount	0		0
Cleco Power [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Cash and Cash Equivalents	19,000,000		18,700,000
Price Risk Derivative [Member] | Cleco Power [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	7,683,000	$ 7,398,000
Unrealized gains (losses)	2,104,000	(832,000)
Purchases	275,000	46,000
Settlements	(5,644,000)	(4,746,000)
Ending balance	4,418,000	1,866,000
Measured On A Recurring Basis [Member]
Asset Description [Abstract]
Institutional money market funds	56,624,000		66,410,000
FTR assets	4,957,000		7,884,000
Total Assets	61,581,000		74,294,000
Liability Description [Abstract]
FTR liabilities	539,000		201,000
Total Liabilities	539,000		201,000
Measured On A Recurring Basis [Member] | Cleco Power [Member]
Asset Description [Abstract]
Institutional money market funds	56,598,000		65,089,000
FTR assets	4,957,000		7,884,000
Total Assets	61,555,000		72,973,000
Liability Description [Abstract]
FTR liabilities	539,000		201,000
Total Liabilities	539,000		201,000
Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]
Asset Description [Abstract]
Institutional money market funds	0		0
FTR assets	0		0
Total Assets	0		0
Liability Description [Abstract]
FTR liabilities	0		0
Total Liabilities	0		0
Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Cleco Power [Member]
Asset Description [Abstract]
Institutional money market funds	0		0
FTR assets	0		0
Total Assets	0		0
Liability Description [Abstract]
FTR liabilities	0		0
Total Liabilities	0		0
Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member]
Asset Description [Abstract]
Institutional money market funds	56,624,000		66,410,000
FTR assets	0		0
Total Assets	56,624,000		66,410,000
Liability Description [Abstract]
FTR liabilities	0		0
Total Liabilities	0		0
Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Cleco Power [Member]
Asset Description [Abstract]
Institutional money market funds	56,598,000		65,089,000
FTR assets	0		0
Total Assets	56,598,000		65,089,000
Liability Description [Abstract]
FTR liabilities	0		0
Total Liabilities	0		0
Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member]
Asset Description [Abstract]
Institutional money market funds	0		0
FTR assets	4,957,000		7,884,000
Total Assets	4,957,000		7,884,000
Liability Description [Abstract]
FTR liabilities	539,000		201,000
Total Liabilities	539,000		201,000
Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member] | Cleco Power [Member]
Asset Description [Abstract]
Institutional money market funds	0		0
FTR assets	4,957,000		7,884,000
Total Assets	4,957,000		7,884,000
Liability Description [Abstract]
FTR liabilities	539,000		201,000
Total Liabilities	539,000		201,000
Restricted Cash and Cash Equivalents, Current [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Institutional Money Market Funds	14,100,000		23,100,000
Restricted Cash and Cash Equivalents, Current [Member] | Cleco Power [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Institutional Money Market Funds	14,100,000		23,100,000
Restricted Cash and Cash Equivalents, Noncurrent [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Institutional Money Market Funds	23,500,000		23,300,000
Restricted Cash and Cash Equivalents, Noncurrent [Member] | Cleco Power [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Fair Value, Concentration of Risk, Amount of Money Market Funds in Institutional Money Market Funds	23,500,000		$ 23,300,000
Successor [Member] | Price Risk Derivative [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	7,683,000
Unrealized gains (losses)	2,104,000
Purchases	275,000
Settlements	(5,644,000)
Ending balance	$ 4,418,000
Predecessor [Member] | Price Risk Derivative [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance		7,398,000
Unrealized gains (losses)		(832,000)
Purchases		46,000
Settlements		(4,746,000)
Ending balance		$ 1,866,000

XML

Fair Value Accounting, Commodity Contracts (Details) $ in Thousands, MWh in Millions	3 Months Ended
	Mar. 31, 2017 USD ($) MMBTU MWh	Mar. 31, 2016 USD ($)	Dec. 31, 2016 USD ($) MMBTU MWh
Cleco Power [Member]
FTRs [Abstract]
Number of FTRs Held (MWh) | MWh	3.6		9.0
Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member]
FTRs, at Fair Value, Net [Abstract]
Commodity-related contracts, net	$ 4,418		$ 7,683
Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Energy risk management asset [Member]
FTRs, at Fair Value, Net [Abstract]
FTRs in energy risk management assets	4,957		7,884
Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Energy risk management liabilities [Member]
FTRs, at Fair Value, Net [Abstract]
FTRs in Energy risk management liabilities	539		201
Price Risk Derivative [Member] | Cleco Power [Member] | Derivatives Not Designated As Hedging Instrument [Member]
FTRs, at Fair Value, Net [Abstract]
Commodity-related contracts, net	4,418		7,683
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income	4,498	$ 2,797
Price Risk Derivative [Member] | Cleco Power [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Accumulated deferred fuel [Member]
FTRs [Abstract]
Derivative, Unrealized Gain (Loss) on Derivative, Net	2,100	(800)
Price Risk Derivative [Member] | Cleco Power [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Energy risk management asset [Member]
FTRs, at Fair Value, Net [Abstract]
FTRs in energy risk management assets	4,957		7,884
Price Risk Derivative [Member] | Cleco Power [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Energy risk management liabilities [Member]
FTRs, at Fair Value, Net [Abstract]
FTRs in Energy risk management liabilities	539		$ 201
Price Risk Derivative [Member] | Cleco Power [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Power purchased for utility customers [Member]
FTRs [Abstract]
Loss on FTRs recognized in income	(4,665)	(5,723)
Price Risk Derivative [Member] | Cleco Power [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Electric operations [Member]
FTRs [Abstract]
Gain on FTRs recognized in income	$ 9,163	8,520
Energy Related Derivative [Member] | Cleco Power [Member]
FTRs [Abstract]
Number of open natural gas positions | MMBTU	0		0
Predecessor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member]
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income		2,797
Predecessor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Power purchased for utility customers [Member]
FTRs [Abstract]
Loss on FTRs recognized in income		(5,723)
Predecessor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Electric operations [Member]
FTRs [Abstract]
Gain on FTRs recognized in income		8,520
Successor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member]
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income	$ 4,498
Successor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Accumulated deferred fuel [Member]
FTRs [Abstract]
Derivative, Unrealized Gain (Loss) on Derivative, Net	2,100	$ 800
Successor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Power purchased for utility customers [Member]
FTRs [Abstract]
Loss on FTRs recognized in income	(4,665)
Successor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated As Hedging Instrument [Member] | Electric operations [Member]
FTRs [Abstract]
Gain on FTRs recognized in income	$ 9,163

XML

Debt, Long-term Debt (Details) - USD ($) $ in Thousands			3 Months Ended
	Apr. 28, 2017	Mar. 01, 2017	Mar. 31, 2017	Mar. 31, 2016	May 17, 2016	Mar. 31, 2008
Cleco Katrina Rita's storm recovery bonds, 5.61, due 2023 [Member]
Debt Instrument [Line Items]
Debt amount						$ 180,600
Cleco Katrina Rita's storm recovery bonds, 5.61, due 2023 [Member]
Debt Instrument [Line Items]
Debt amount						$ 113,000
Interest rate, stated percentage (in hundredths)						4.41%
Repayment of Senior Notes through cash		$ 1,100
Interest Expense, Debt		$ 100
Cleco Holdings [Member] | Cleco Holdings' senior notes, 4.973%, due 2046 [Member]
Debt Instrument [Line Items]
Debt amount					$ 350,000
Interest rate, stated percentage (in hundredths)					4.973%
Cleco Holdings [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member]
Debt Instrument [Line Items]
Debt amount					$ 1,350,000
Cleco Holdings [Member] | Cleco Holdings' senior notes, 3.743%, due 2026 [Member]
Debt Instrument [Line Items]
Debt amount					$ 535,000
Interest rate, stated percentage (in hundredths)					3.743%
Subsidiaries [Member]
Debt Instrument [Line Items]
Repayment of Senior Notes through cash			$ 9,060	$ 8,546
Subsequent Event [Member] | Cleco Holdings [Member] | Cleco Holdings' senior notes, 4.973%, due 2046 [Member]
Debt Instrument [Line Items]
Interest rate on original debt (in hundredths)	4.973%
Interest rate on converted debt (in hundredths)	4.973%
Subsequent Event [Member] | Cleco Holdings [Member] | Cleco Holdings' senior notes, 3.743%, due 2026 [Member]
Debt Instrument [Line Items]
Interest rate on original debt (in hundredths)	3.743%
Interest rate on converted debt (in hundredths)	3.743%

XML

Pension Plan and Employee Benefits, Pension Plan and Other Benefits Plan (Details) - USD ($)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Other Benefits [Member]
Components of periodic benefit costs [Abstract]
Assets Held-in-trust, Noncurrent	$ 0
Current portion of other benefits liability	3,854,000		$ 3,854,000
Noncurrent portion of other benefits liability	39,934,000		40,196,000
Other Benefits [Member] | Cleco Power [Member]
Components of periodic benefit costs [Abstract]
Net periodic benefit cost	900,000	$ 800,000
Current portion of other benefits liability	3,345,000		3,345,000
Noncurrent portion of other benefits liability	34,668,000		$ 34,892,000
Successor [Member] | Pension Benefits [Member]
Components of periodic benefit costs [Abstract]
Service cost	2,225,000
Interest cost	5,358,000
Expected return on plan assets	(6,138,000)
Prior period service (credit) cost	(18,000)
Net loss (gain)	2,413,000
Net periodic benefit cost	3,840,000
Successor [Member] | Pension Benefits [Member] | Other Subsidiaries [Member]
Components of periodic benefit costs [Abstract]
Net periodic benefit cost	400,000
Successor [Member] | Other Benefits [Member]
Components of periodic benefit costs [Abstract]
Service cost	385,000
Interest cost	403,000
Expected return on plan assets	0
Prior period service (credit) cost	0
Net loss (gain)	(3,000)
Net periodic benefit cost	$ 785,000
Predecessor [Member] | Pension Benefits [Member]
Components of periodic benefit costs [Abstract]
Service cost		2,262,000
Interest cost		5,507,000
Expected return on plan assets		(6,010,000)
Prior period service (credit) cost		(18,000)
Net loss (gain)		2,469,000
Net periodic benefit cost		4,210,000
Predecessor [Member] | Pension Benefits [Member] | Other Subsidiaries [Member]
Components of periodic benefit costs [Abstract]
Net periodic benefit cost		400,000
Predecessor [Member] | Other Benefits [Member]
Components of periodic benefit costs [Abstract]
Service cost		380,000
Interest cost		420,000
Expected return on plan assets		0
Prior period service (credit) cost		30,000
Net loss (gain)		160,000
Net periodic benefit cost		$ 990,000

XML

Pension Plan and Employee Benefits, SERP (Details) - SERP Benefits [Member] - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Mar. 30, 2017	Mar. 29, 2017	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate (in hundredths)			4.08%	4.22%
Components of periodic benefit costs [Abstract]
Current portion of SERP liability	$ 4,308				$ 4,308
Noncurrent portion of SERP liability	77,329				73,738
Cleco Power [Member]
Components of periodic benefit costs [Abstract]
Total benefit cost	300	$ 400
Current portion of SERP liability	885				885
Noncurrent portion of SERP liability	16,075				$ 15,145
Successor [Member]
Components of periodic benefit costs [Abstract]
Service cost	145
Interest cost	800
Prior period service (credit) cost	(57)
Net loss (gain)	419
Net periodic benefit cost	1,307
Special/contractual termination benefits	315
Total benefit cost	$ 1,622
Predecessor [Member]
Components of periodic benefit costs [Abstract]
Service cost		583
Interest cost		731
Prior period service (credit) cost		13
Net loss (gain)		655
Net periodic benefit cost		1,982
Special/contractual termination benefits		0
Total benefit cost		$ 1,982

XML

Pension Plan and Employee Benefits, 401 (K) Plans (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Successor [Member]
401(k) Plan [Abstract]
401(k) Plan expense	$ 1,668
Successor [Member] | Other Subsidiaries [Member]
401(k) Plan [Abstract]
401(k) Plan expense	$ 279
Predecessor [Member]
401(k) Plan [Abstract]
401(k) Plan expense		$ 1,374
Predecessor [Member] | Other Subsidiaries [Member]
401(k) Plan [Abstract]
401(k) Plan expense		$ 282

XML

Income Taxes, Effective Tax Rate Reconciliation (Details)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Cleco Power [Member]
Effective Income Tax Rate [Line Items]
Effective income tax rates	35.60%	37.60%
Successor [Member]
Effective Income Tax Rate [Line Items]
Effective income tax rates	33.10%
Predecessor [Member]
Effective Income Tax Rate [Line Items]
Effective income tax rates		38.50%

XML

Income Taxes, Valuation Allowance (Details) - NMTC [Member] - USD ($)	Mar. 31, 2017	Dec. 31, 2016
NMTC Carryforward [Line Items]
Deferred Tax Asset	$ 97,500,000	$ 97,500,000
Valuation Allowance	$ 0	$ 0

XML

Income Taxes, Net Operating Losses (Details) $ in Millions	Mar. 31, 2017 USD ($)
Federal [Member]
Net Operating Losses [Line Items]
Net Operating Loss Carryforward	$ 82.1
State [Member]
Net Operating Losses [Line Items]
Net Operating Loss Carryforward	$ 193.1

XML

Income Taxes, Uncertain Tax Positions (Details) - USD ($)	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Uncertain Tax Positions [Line Items]
Interest payable related to uncertain tax positions	$ 0		$ 0
Liability for uncertain tax positions	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
Predecessor [Member]
Uncertain Tax Positions [Line Items]
Interest expense related to uncertain tax positions		0
Penalties		$ 0
Successor [Member]
Uncertain Tax Positions [Line Items]
Interest expense related to uncertain tax positions	0
Penalties	$ 0

XML

Disclosures about Segments (Details) $ in Thousands	3 Months Ended
	Mar. 31, 2017 USD ($) entity	Mar. 31, 2016 USD ($)	Dec. 31, 2016 USD ($)	Apr. 13, 2016 USD ($)
Segment Reporting Information [Line Items]
Number of transmission interconnection facility subsidiaries | entity	2
Revenue [Abstract]
Net (loss) income	$ 6,292
Equity investment in investees	18,672		$ 18,672
Goodwill	1,490,797		1,490,797	$ 1,490,797
Total segment assets	6,335,981		6,343,144
Predecessor [Member]
Revenue [Abstract]
Electric operations		$ 250,157
Other operations		17,132
Electric customer credits		(321)
Affiliate revenue		0
Operating revenue, net		266,968
Depreciation and amortization		38,938
Merger transaction and commitment costs		1,522
Interest charges		19,553
Interest income		224
Federal and state income tax (benefit) expense		12,137
Net (loss) income		19,368
Additions to property, plant, and equipment		35,476
Predecessor [Member] | Operating Segments [Member] | Cleco Power [Member]
Revenue [Abstract]
Electric operations		250,157
Other operations		16,614
Electric customer credits		(321)
Affiliate revenue		232
Operating revenue, net		266,682
Depreciation and amortization		38,603
Merger transaction and commitment costs		0
Interest charges		19,285
Interest income		179
Federal and state income tax (benefit) expense		12,563
Net (loss) income		20,879
Additions to property, plant, and equipment		35,453
Predecessor [Member] | Operating Segments [Member] | Other [Member]
Revenue [Abstract]
Electric operations		0
Other operations		518
Electric customer credits		0
Affiliate revenue		13,024
Operating revenue, net		13,542
Depreciation and amortization		335
Merger transaction and commitment costs		1,539
Interest charges		278
Interest income		55
Federal and state income tax (benefit) expense		(426)
Net (loss) income		(1,511)
Additions to property, plant, and equipment		23
Predecessor [Member] | Intersegment Elimination [Member]
Revenue [Abstract]
Electric operations		0
Other operations		0
Electric customer credits		0
Affiliate revenue		(13,256)
Operating revenue, net		(13,256)
Depreciation and amortization		0
Merger transaction and commitment costs		(17)
Interest charges		(10)
Interest income		(10)
Federal and state income tax (benefit) expense		0
Net (loss) income		0
Additions to property, plant, and equipment		$ 0
Successor [Member]
Revenue [Abstract]
Electric operations	234,056
Other operations	16,880
Electric customer credits	(435)
Affiliate revenue	0
Operating revenue, net	250,501
Depreciation and amortization	40,851
Merger transaction and commitment costs	99
Interest charges	31,718
Interest income	312
Federal and state income tax (benefit) expense	3,107
Net (loss) income	6,292
Additions to property, plant, and equipment	47,890
Equity investment in investees	18,672		18,672
Goodwill	1,490,797		1,490,797
Total segment assets	6,335,981		6,343,144
Successor [Member] | Operating Segments [Member] | Cleco Power [Member]
Revenue [Abstract]
Electric operations	237,553
Other operations	16,365
Electric customer credits	(435)
Affiliate revenue	219
Operating revenue, net	253,702
Depreciation and amortization	38,758
Merger transaction and commitment costs	0
Interest charges	18,104
Interest income	266
Federal and state income tax (benefit) expense	9,855
Net (loss) income	17,854
Additions to property, plant, and equipment	46,744
Equity investment in investees	18,672		18,672
Goodwill	1,490,797		1,490,797
Total segment assets	5,748,503		5,758,245
Successor [Member] | Operating Segments [Member] | Other [Member]
Revenue [Abstract]
Electric operations	(3,497)
Other operations	515
Electric customer credits	0
Affiliate revenue	14,734
Operating revenue, net	11,752
Depreciation and amortization	2,093
Merger transaction and commitment costs	99
Interest charges	13,681
Interest income	113
Federal and state income tax (benefit) expense	(6,748)
Net (loss) income	(11,562)
Additions to property, plant, and equipment	1,146
Equity investment in investees	0		0
Goodwill	0		0
Total segment assets	621,406		614,959
Successor [Member] | Intersegment Elimination [Member]
Revenue [Abstract]
Electric operations	0
Other operations	0
Electric customer credits	0
Affiliate revenue	(14,953)
Operating revenue, net	(14,953)
Depreciation and amortization	0
Merger transaction and commitment costs	0
Interest charges	(67)
Interest income	(67)
Federal and state income tax (benefit) expense	0
Net (loss) income	0
Additions to property, plant, and equipment	0
Equity investment in investees	0		0
Goodwill	0		0
Total segment assets	$ (33,928)		$ (30,060)

XML

Regulation and Rates (Details) - USD ($)			1 Months Ended		3 Months Ended	33 Months Ended
	Feb. 13, 2017	Sep. 29, 2016	Jun. 30, 2016	Nov. 30, 2013	Mar. 31, 2017	Mar. 31, 2017	Dec. 31, 2016	Oct. 31, 2016	Apr. 07, 2016
Regulation and Rates [Line Items]
Refund due to customers					$ 3,262,000	$ 3,262,000	$ 3,974,000
FERC [Member] | MISO Transmission Rates [Member]
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%
Cleco Power [Member]
Regulation and Rates [Line Items]
Refund due to customers					3,262,000	3,262,000	3,974,000
Cleco Power [Member] | FERC [Member] | MISO Transmission Rates [Member]
Regulation and Rates [Line Items]
Customer Refundable Fees, Refund Payments	$ 1,200,000
Cleco Power [Member] | FERC [Member] | ROE reduction of transmission rates [Member]
Regulation and Rates [Line Items]
Refund due to customers					1,900,000	$ 1,900,000
Cleco Power [Member] | LPSC [Member] | FRP Monitoring report for the 12-month period ended June 30, 2016 [Member]
Regulation and Rates [Line Items]
Refund due to customers								$ 0
Cleco Power [Member] | LPSC [Member] | FRP [Member]
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] | LPSC [Member] | Merger Commitment Monitoring report for the 12-month period ended June 30, 2016 [Member]
Regulation and Rates [Line Items]
Refund due to customers								$ 300,000
Maximum [Member] | Cleco Power [Member] | LPSC [Member] | FRP [Member]
Regulation and Rates [Line Items]
Target ROE allowed by FRP (in hundredths)						10.90%
Merger Commitments, rate credits [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments									$ 136,000,000
Merger Commitments, rate credits [Member] | Cleco Power [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments									136,000,000
Rate Credits issued to customers					125,000,000
Merger Commitments, economic development contribution [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments									7,000,000
Merger Commitments, economic development contribution [Member] | Cleco Power [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments							$ 7,000,000		7,000,000
Merger Commitments, charitable contribution, disbursed over 5 years [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments									6,000,000
Merger Commitments, charitable contribution, disbursed over 5 years [Member] | Cleco Power [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments									6,000,000
Merger Commitments, economic development contribution, disbursed over 5 years [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments									2,500,000
Merger Commitments, economic development contribution, disbursed over 5 years [Member] | Cleco Power [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments									2,500,000
Merger Commitments, cost savings [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Merger Commitments									1,200,000
Merger Commitments, cost savings [Member] | Cleco Power [Member] | LPSC [Member]
Regulation and Rates [Line Items]
Refund due to customers					$ 1,200,000	$ 1,200,000
Merger Commitments									$ 1,200,000

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Variable Interest Entities (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016	Dec. 31, 2016
Variable Interest Entity [Line Items]
Equity investment in investees	$ 18,672		$ 18,672
Components of equity method investments [Abstract]
Total equity investment in investee	18,672		18,672
Cleco Power [Member]
Variable Interest Entity [Line Items]
Equity investment in investees	18,672		18,672
Components of equity method investments [Abstract]
Purchase price	12,873		12,873
Cash contributions	6,399		6,399
Dividend received	(600)		(600)
Total equity investment in investee	18,672		18,672
Comparison of carrying amount of assets and liabilities to maximum loss exposure [Abstract]
Partners' capital	37,345		37,345
Equity Method Investment, Summarized Financial Information [Abstract]
Operating revenue	1,073	$ 2,101
Operating expenses	1,073	2,101
Income before taxes	$ 0	$ 0
Oxbow [Member] | Cleco Power [Member]
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	$ 18,672		18,672
Cleco Power’s maximum exposure to loss	$ 18,672		$ 18,672

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Litigation (Details)			1 Months Ended				24 Months Ended	62 Months Ended
	Feb. 13, 2017 USD ($)	Sep. 29, 2016	Jun. 30, 2016	Sep. 30, 2015 USD ($)	Nov. 30, 2014	Nov. 30, 2013	Dec. 31, 2015 USD ($)	Dec. 31, 2015 USD ($)	Mar. 31, 2017 USD ($)	Jan. 19, 2017 USD ($)	Dec. 31, 2016 USD ($)	Dec. 01, 2016 USD ($)	Jun. 24, 2016 petition
Litigation [Abstract]
Provision for rate refund									$ 3,262,000		$ 3,974,000
Loss Contingency, Estimate of Possible Loss									4,800,000
Gulf Coast Spinning start up costs [Member]
Litigation [Abstract]
Allegations by plaintiff, failure to perform				$ 6,500,000
Gulf Coast Spinning construction of cotton spinning facility [Member]
Litigation [Abstract]
Allegations by plaintiff, failure to perform				$ 60,000,000
Cleco Power [Member]
Litigation [Abstract]
Provision for rate refund									3,262,000		$ 3,974,000
LPSC 2014-2015 Fuel Audit [Member] | Cleco Power [Member]
Litigation [Abstract]
Fuel Costs							$ 582,600,000
Cost disallowance in audit, excluding interest										$ 0
LPSC Nov2010-Dec2015 EAC audit [Member] | Cleco Power [Member]
Litigation [Abstract]
Environmental expenses included in audit								$ 81,200,000
Number of petitions filed with the U.S. Court of Appeals | petition													6
FERC [Member] | MISO Transmission Rates [Member]
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%
Public Utilities, Requested rate increase (decrease), Percentage (in hundredths)					0.50%
FERC [Member] | MISO Transmission Rates [Member] | Cleco Power [Member]
Litigation [Abstract]
Customer Refundable Fees, Refund Payments	$ 1,200,000
FERC [Member] | Transmission Return on Equity [Member] | Cleco Power [Member]
Litigation [Abstract]
Provision for rate refund									$ 1,900,000
Maximum [Member] | LPSC Nov2010-Dec2015 EAC audit [Member] | Cleco Power [Member]
Litigation [Abstract]
Cost disallowance in audit, excluding interest												$ 100,000

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Off-Balance Sheet Commitments and Guarantees (Details) $ in Millions	Mar. 31, 2017 USD ($)
Performance Guarantee [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 42.4
Indemnification Agreement [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	40.0
Indemnification Agreement including fundamental organizational structure [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	400.0
Cleco Power [Member] | Indemnification Agreement [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	40.0
Cleco Power [Member] | Indemnification Agreement including fundamental organizational structure [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	400.0
Cleco Power [Member] | Financial Guarantee [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 106.5

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Other Commitments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2008
Other Commitments [Abstract]
Equity contributions to be made to the Fund	$ 285.5
Net tax benefits and cash to be received from the Fund	303.8
Membership interest in U.S Bank New Markets Tax Credit Fund (in hundredths)			99.90%
Tax Benefits in Excess of Capital Contributions	18.1
Difference between equity contributions and total benefits received	$ 18.3
Liability component contained in the net asset		$ 0.6
Period of recognition of gross investment amortization expense (in years)	10 years

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Affiliate Transactions (Details) - Cleco Power [Member] - USD ($) $ in Thousands	Mar. 31, 2017	Dec. 31, 2016
Related Party Transaction [Line Items]
Accounts receivable - affiliate	$ 1,378	$ 1,406
Accounts payable - affiliate	9,367	7,190
Cleco Group [Member]
Related Party Transaction [Line Items]
Accounts receivable - affiliate	1	3
Accounts payable - affiliate	176	119
Support Group [Member]
Related Party Transaction [Line Items]
Accounts receivable - affiliate	1,377	1,402
Accounts payable - affiliate	9,191	7,071
Subsidiary of Common Parent [Member]
Related Party Transaction [Line Items]
Accounts receivable - affiliate	0	1
Accounts payable - affiliate	$ 0	$ 0

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Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2017	Mar. 31, 2016
Accumulated other comprehensive loss [Roll Forward]
Balances	$ 2,046,763
Net current-period other comprehensive income [Abstract]
Net current-period other comprehensive income	(2,191)
Balances	2,021,909
Total AOCI [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances	1,500
Net current-period other comprehensive income [Abstract]
Net current-period other comprehensive income	(2,191)
Balances	(691)
Cleco Power [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances	1,535,202
Net current-period other comprehensive income [Abstract]
Net current-period other comprehensive income	(367)	$ 253
Balances	1,517,689
Cleco Power [Member] | Total AOCI [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances	(13,422)	(17,092)
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period	(584)
Amounts reclassified from accumulated other comprehensive income, net of tax	164	200
Net current-period other comprehensive income	(367)	253
Balances	(13,789)	(16,839)
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
Cleco Power [Member] | Postretirement Benefit Net Loss [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances	(7,905)	(11,364)
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period	(584)
Amounts reclassified from accumulated other comprehensive income, net of tax	164	200
Net current-period other comprehensive income	(420)	200
Balances	(8,325)	(11,164)
Cleco Power [Member] | Net Loss on Cash Flow Hedges [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances	(5,517)	(5,728)
Net current-period other comprehensive income [Abstract]
Net current-period other comprehensive income	53	53
Balances	(5,464)	(5,675)
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
Predecessor [Member]
Net current-period other comprehensive income [Abstract]
Net current-period other comprehensive income		581
Predecessor [Member] | Total AOCI [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances		(26,585)
Net current-period other comprehensive income [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax		528
Net current-period other comprehensive income		581
Balances		(26,004)
Predecessor [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
Predecessor [Member] | Postretirement Benefit Net Loss [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances		(20,857)
Net current-period other comprehensive income [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax		528
Net current-period other comprehensive income		528
Balances		(20,329)
Predecessor [Member] | Net Loss on Cash Flow Hedges [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances		(5,728)
Net current-period other comprehensive income [Abstract]
Net current-period other comprehensive income		53
Balances		(5,675)
Predecessor [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
Successor [Member]
Net current-period other comprehensive income [Abstract]
Net current-period other comprehensive income	(2,191)
Successor [Member] | Total AOCI [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances	1,500
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period	(2,065)
Amounts reclassified from accumulated other comprehensive income, net of tax	(126)
Net current-period other comprehensive income	(2,191)
Balances	(691)
Successor [Member] | Postretirement Benefit Net Loss [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances	1,500
Net current-period other comprehensive income [Abstract]
Postretirement benefit adjustments during the period	(2,065)
Amounts reclassified from accumulated other comprehensive income, net of tax	(126)
Net current-period other comprehensive income	(2,191)
Balances	(691)
Successor [Member] | Net Loss on Cash Flow Hedges [Member]
Accumulated other comprehensive loss [Roll Forward]
Balances	0
Net current-period other comprehensive income [Abstract]
Net current-period other comprehensive income	0
Balances	$ 0