Cleco Power 10-K 22 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($)	12 Months Ended
	Dec. 31, 2016	Feb. 22, 2017	Jun. 30, 2016
Entity Information [Line Items]
Entity Registrant Name	CLECO CORPORATE HOLDINGS LLC
Entity Central Index Key	1,089,819
Current Fiscal Year End Date	--12-31
Entity Filer Category	Non-accelerated Filer
Document Type	10-K
Document Period End Date	Dec. 31, 2016
Document Fiscal Year Focus	2,016
Document Fiscal Period Focus	FY
Amendment Flag	false
Entity Common Stock, Shares Outstanding		0
Entity Well-known Seasoned Issuer	No
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Public Float			$ 0
Cleco Power [Member]
Entity Information [Line Items]
Entity Registrant Name	CLECO POWER LLC
Entity Central Index Key	18,672
Entity Filer Category	Non-accelerated Filer
Entity Well-known Seasoned Issuer	No

Consolidated Statements of Inco

Consolidated Statements of Income - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Operating revenue [Abstract]
Electric operations			$ 1,091,229	$ 1,142,389	$ 1,225,960
Other operations			68,573	67,109	64,893
Affiliate revenue			884	1,142	1,326
Gross operating revenue			1,160,686	1,210,640	1,292,179
Electric customer credits			(1,513)	(2,173)	(23,530)
Operating revenue, net			1,159,173	1,208,467	1,268,649
Operating expenses [Abstract]
Fuel used for electric generation			346,520	373,117	322,696
Power purchased for utility customers			119,586	130,095	247,686
Other operations			125,892	128,697	116,664
Maintenance			93,340	87,416	96,054
Depreciation and amortization			146,142	147,839	144,026
Taxes other than income taxes			48,287	47,102	41,812
Merger transaction and commitment costs			151,501	0	0
Gain on sales of assets			(1,095)	0	(4)
Total operating expenses			1,030,173	914,266	968,934
Operating income (loss)			129,000	294,201	299,715
Interest income			860	725	1,707
Allowance for equity funds used during construction			4,458	3,063	5,380
Other income			1,601	1,764	1,483
Other expense			(1,976)	(2,549)	(2,322)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net			77,739	77,446	76,253
Allowance for borrowed funds used during construction			(1,293)	(886)	(1,580)
Total interest charges			76,446	76,560	74,673
(Loss) income before income taxes			57,497	220,644	231,290
Federal and state income tax (benefit) expense			18,369	79,294	76,974
Net (loss) income			$ 39,128	141,350	154,316
Predecessor [Member]
Operating revenue [Abstract]
Electric operations	$ 281,154			1,142,389	1,225,960
Other operations	19,080			69,186	67,055
Affiliate revenue	0			0	0
Gross operating revenue	300,234			1,211,575	1,293,015
Electric customer credits	(364)			(2,173)	(23,530)
Operating revenue, net	299,870			1,209,402	1,269,485
Operating expenses [Abstract]
Fuel used for electric generation	96,378			373,117	322,696
Power purchased for utility customers	27,249			130,095	242,219
Other operations	33,563			127,410	117,369
Maintenance	29,813			88,137	98,999
Depreciation and amortization	44,076			149,579	146,505
Taxes other than income taxes	14,611			49,134	43,924
Merger transaction and commitment costs	34,912			4,591	17,848
Gain on sales of assets	(1,095)			0	(6,107)
Total operating expenses	279,507			922,063	983,453
Operating income (loss)	20,363			287,339	286,032
Interest income	265			895	1,768
Allowance for equity funds used during construction	723			3,063	5,380
Other income	870			1,443	4,790
Other expense	(590)			(3,376)	(2,509)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net	22,330			78,877	75,186
Allowance for borrowed funds used during construction	(207)			(886)	(1,580)
Total interest charges	22,123			77,991	73,606
(Loss) income before income taxes	(492)			211,373	221,855
Federal and state income tax (benefit) expense	3,468			77,704	67,116
Net (loss) income	$ (3,960)			$ 133,669	$ 154,739
Successor [Member]
Operating revenue [Abstract]
Electric operations		$ 802,592
Other operations		51,562
Affiliate revenue		0
Gross operating revenue		854,154
Electric customer credits		(1,149)
Operating revenue, net		853,005
Operating expenses [Abstract]
Fuel used for electric generation		250,142
Power purchased for utility customers		92,337
Other operations		90,313
Maintenance		63,944
Depreciation and amortization		109,739
Taxes other than income taxes		35,543
Merger transaction and commitment costs		174,696
Gain on sales of assets		0
Total operating expenses		816,714
Operating income (loss)		36,291
Interest income		840
Allowance for equity funds used during construction		3,735
Other income		3,350
Other expense		(1,385)
Interest charges [Abstract]
Interest charges, including amortization of debt issuance costs, premiums, and discounts, net		90,852
Allowance for borrowed funds used during construction		(1,086)
Total interest charges		89,766
(Loss) income before income taxes		(46,935)
Federal and state income tax (benefit) expense		(22,822)
Net (loss) income		$ (24,113)

Consolidated Statements of Comp

Consolidated Statements of Comprehensive Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Net (loss) income	$ 39,128	$ 141,350	$ 154,316
Other comprehensive income (loss), net of tax:
Postretirement benefits gain (loss), net of tax	3,459	(15)	(2,323)
Net gain on cash flow hedges, net of tax	211	211	212
Total other comprehensive income (loss), net of tax	3,670	196	(2,111)
Comprehensive income, net of tax	$ 42,798	141,546	152,205
Predecessor [Member]
Net (loss) income		133,669	154,739
Other comprehensive income (loss), net of tax:
Postretirement benefits gain (loss), net of tax		5,869	(7,001)
Net gain on cash flow hedges, net of tax		211	212
Total other comprehensive income (loss), net of tax		6,080	(6,789)
Comprehensive income, net of tax		$ 139,749	$ 147,950

Consolidated Statements of Com4

Consolidated Statements of Comprehensive Income (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Net tax expense (benefit) on post-retirement benefits	$ 2,163	$ (9)	$ (1,453)
Net tax expense on cash flow hedges	$ 132	132	132
Predecessor [Member]
Net tax expense (benefit) on post-retirement benefits		3,670	(4,378)
Net tax expense on cash flow hedges		$ 132	$ 132

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Cleco Power [Member]
Current Assets [Abstract]
Cash and cash equivalents	$ 21,482,000	$ 65,705,000
Restricted cash and cash equivalents	23,084,000	9,263,000
Customer accounts receivable (less allowance for doubtful accounts)	56,780,000	43,255,000
Accounts receivable - affiliate	1,406,000	1,908,000
Other accounts receivable	19,457,000	27,553,000
Taxes receivable, net	12,490,000	0
Unbilled revenue	34,268,000	33,995,000
Fuel inventory, at average cost	46,410,000	72,838,000
Materials and supplies, at average cost	81,818,000	76,731,000
Energy risk management assets	7,884,000	7,673,000
Accumulated deferred fuel	20,787,000	12,910,000
Cash surrender value of company-/trust-owned life insurance policies	20,018,000	20,003,000
Prepayments	5,892,000	6,309,000
Regulatory assets	17,721,000	14,117,000
Other current assets	577,000	337,000
Total current assets	370,074,000	392,597,000
Property, Plant, and Equipment [Abstract]
Property, plant, and equipment	4,790,565,000	4,645,698,000
Accumulated depreciation	(1,618,241,000)	(1,525,298,000)
Net property, plant, and equipment	3,172,324,000	3,120,400,000
Construction work in progress	77,306,000	66,069,000
Total property, plant, and equipment, net	3,249,630,000	3,186,469,000
Equity investment in investee	18,672,000	16,822,000
Prepayments	4,731,000	4,542,000
Restricted cash and cash equivalents	23,389,000	16,174,000
Regulatory assets - deferred taxes, net	237,449,000	236,941,000
Regulatory assets	268,016,000	284,689,000
Intangible assets	58,473,000	74,963,000
Other deferred charges	37,014,000	20,140,000
Total assets	4,267,448,000	4,233,337,000
Current Liabilities [Abstract]
Long-term debt due within one year	19,715,000	19,421,000
Accounts payable	101,874,000	88,235,000
Accounts payable - affiliate	7,190,000	6,598,000
Customer deposits	56,599,000	55,233,000
Provision for rate refund	3,974,000	2,696,000
Provisions for merger commitments, Current	14,371,000	0
Taxes payable	0	17,045,000
Interest accrued	7,141,000	7,813,000
Energy risk management liabilities	201,000	275,000
Regulatory liabilities - other	0	312,000
Other current liabilities	9,951,000	10,078,000
Total current liabilities	221,016,000	207,706,000
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	1,068,592,000	1,043,531,000
Accumulated deferred investment tax credits	2,751,000	3,245,000
Postretirement benefit obligations	159,107,000	152,152,000
Restricted storm reserve	17,385,000	16,177,000
Other deferred credits	28,339,000	24,083,000
Total long-term liabilities and deferred credits	1,276,174,000	1,239,188,000
Long-term debt, net	1,235,056,000	1,234,039,000
Total capitalization	2,770,258,000	2,786,443,000
Commitments and contingencies (Note 15)
Shareholders’ Equity [Abstract]
Total liabilities and member’s equity/shareholders’ equity	4,267,448,000	4,233,337,000
Members' Equity	1,535,202,000	1,552,404,000
Predecessor [Member]
Current Assets [Abstract]
Cash and cash equivalents		68,246,000
Restricted cash and cash equivalents		9,263,000
Customer accounts receivable (less allowance for doubtful accounts)		43,255,000
Other accounts receivable		27,677,000
Unbilled revenue		33,995,000
Fuel inventory, at average cost		72,838,000
Materials and supplies, at average cost		76,731,000
Energy risk management assets		7,673,000
Accumulated deferred fuel		12,910,000
Cash surrender value of company-/trust-owned life insurance policies		73,823,000
Prepayments		7,883,000
Regulatory assets		14,117,000
Other current assets		448,000
Total current assets		448,859,000
Property, Plant, and Equipment [Abstract]
Property, plant, and equipment		4,661,212,000
Accumulated depreciation		(1,536,158,000)
Net property, plant, and equipment		3,125,054,000
Construction work in progress		66,509,000
Total property, plant, and equipment, net		3,191,563,000
Equity investment in investee		16,822,000
Goodwill		0
Prepayments		4,542,000
Restricted cash and cash equivalents		16,195,000
Regulatory assets - deferred taxes, net		236,941,000
Regulatory assets		284,689,000
Net investment in direct financing lease		13,464,000
Intangible assets		74,963,000
Tax credit fund investment, net		13,741,000
Other deferred charges		21,575,000
Total assets		4,323,354,000
Current Liabilities [Abstract]
Long-term debt due within one year		19,421,000
Accounts payable		93,822,000
Customer deposits		55,233,000
Provision for rate refund		2,696,000
Provisions for merger commitments, Current		0
Taxes payable		2,573,000
Interest accrued		7,814,000
Energy risk management liabilities		275,000
Regulatory liabilities - other		312,000
Deferred compensation		10,156,000
Other current liabilities		14,277,000
Total current liabilities		206,579,000
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net		925,103,000
Accumulated deferred investment tax credits		3,245,000
Postretirement benefit obligations		205,036,000
Restricted storm reserve		16,177,000
Other deferred credits		24,670,000
Total long-term liabilities and deferred credits		1,174,231,000
Long-term debt, net		1,267,703,000
Total liabilities		2,648,513,000
Commitments and contingencies (Note 15)
Shareholders’ Equity [Abstract]
Members' Capital		456,412,000
(Accumulated deficit)/Retained earnings		1,245,014,000
Accumulated other comprehensive income (loss)		(26,585,000)
Total liabilities and member’s equity/shareholders’ equity		4,323,354,000
Members' Equity		$ 1,674,841,000
Successor [Member]
Current Assets [Abstract]
Cash and cash equivalents	23,077,000
Restricted cash and cash equivalents	23,084,000
Customer accounts receivable (less allowance for doubtful accounts)	56,780,000
Other accounts receivable	19,778,000
Unbilled revenue	34,268,000
Fuel inventory, at average cost	46,410,000
Materials and supplies, at average cost	81,818,000
Energy risk management assets	7,884,000
Accumulated deferred fuel	20,787,000
Cash surrender value of company-/trust-owned life insurance policies	77,225,000
Prepayments	7,813,000
Regulatory assets	26,803,000
Other current assets	1,315,000
Total current assets	427,042,000
Property, Plant, and Equipment [Abstract]
Property, plant, and equipment	3,476,581,000
Accumulated depreciation	(75,816,000)
Net property, plant, and equipment	3,400,765,000
Construction work in progress	78,577,000
Total property, plant, and equipment, net	3,479,342,000
Equity investment in investee	18,672,000
Goodwill	1,490,797,000
Prepayments	4,731,000
Restricted cash and cash equivalents	23,410,000
Regulatory assets - deferred taxes, net	237,449,000
Regulatory assets	454,644,000
Net investment in direct financing lease	13,420,000
Intangible assets	142,634,000
Tax credit fund investment, net	11,888,000
Other deferred charges	39,115,000
Total assets	6,343,144,000
Current Liabilities [Abstract]
Long-term debt due within one year	19,715,000
Accounts payable	112,087,000
Customer deposits	56,599,000
Provision for rate refund	3,974,000
Provisions for merger commitments, Current	14,371,000
Taxes payable	3,942,000
Interest accrued	14,783,000
Energy risk management liabilities	201,000
Regulatory liabilities - other	0
Deferred compensation	11,654,000
Other current liabilities	14,850,000
Total current liabilities	252,176,000
Long-term liabilities and deferred credits
Accumulated deferred federal and state income taxes, net	1,033,055,000
Accumulated deferred investment tax credits	2,751,000
Postretirement benefit obligations	223,003,000
Restricted storm reserve	17,385,000
Other deferred credits	29,440,000
Total long-term liabilities and deferred credits	1,305,634,000
Long-term debt, net	2,738,571,000
Total liabilities	4,296,381,000
Commitments and contingencies (Note 15)
Shareholders’ Equity [Abstract]
Members' Capital	2,069,376,000
(Accumulated deficit)/Retained earnings	(24,113,000)
Accumulated other comprehensive income (loss)	1,500,000
Total liabilities and member’s equity/shareholders’ equity	6,343,144,000
Members' Equity	$ 2,046,763,000

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Assets [Abstract]
Customer accounts receivable, allowance for doubtful accounts	$ 0	$ 2,674
Cleco Power [Member]
Assets [Abstract]
Customer accounts receivable, allowance for doubtful accounts	$ 7,199	$ 922
Predecessor [Member]
Liabilities and Shareholders’ Equity [Abstract]
Common stock, par value (in dollars per share)		$ 1
Common stock, authorized (in shares)		100,000,000
Common stock, issued (in shares)		61,058,918
Common stock, outstanding (in shares)		60,482,468
Treasury stock (in shares)		576,450
Premium on common stock		$ 418,500
Common Stock, Value, Issued		61,100
Treasury Stock, Value		$ 23,200

Consolidated Statements of Cash

Consolidated Statements of Cash Flows - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Operating Activities [Abstract]
Net (loss) income			$ 39,128	$ 141,350	$ 154,316
Adjustments to reconcile net income to net cash provided by operating activities [Abstract]
Depreciation and amortization			152,978	152,833	151,252
Gain sale of assets			(1,095)	0	(346)
Provision for doubtful accounts			5,512	2,986	1,994
Unearned compensation expense			1,572	2,000	2,004
Allowance for equity funds used during construction			(4,458)	(3,063)	(5,380)
Net deferred income taxes			20,492	43,675	82,315
Deferred fuel costs			(7,215)	9,899	(11,558)
Provision for merger commitments			21,964	0	0
Changes in assets and liabilities [Abstract]
Accounts receivable			(23,306)	(13,681)	11,689
Accounts and notes receivable, affiliate			2,612	6,195	709
Unbilled revenue			(274)	4,481	(7,310)
Fuel inventory and materials and supplies			22,192	(13,698)	(12,114)
Accounts payable			9,140	(20,575)	5,459
Accounts and notes payable, affiliate			(3,639)	(3,990)	(2,749)
Customer deposits			10,675	12,162	14,960
Postretirement benefit obligations			5,076	7,405	4,963
Regulatory assets and liabilities, net			17,506	18,793	(777)
Other deferred accounts			(21,818)	(15,991)	(10,798)
Taxes accrued			(29,535)	36,287	(26,373)
Interest accrued			(671)	(1,412)	(4,364)
Other operating			(1,079)	882	(820)
Net cash provided by operating activities			215,757	366,538	347,072
Investing Activities [Abstract]
Additions to property, plant, and equipment			(186,143)	(156,357)	(206,607)
Allowance for equity funds used during construction			4,458	3,063	5,380
Proceeds from sale of property, plant, and equipment			2,698	0	0
Reimbursement for property loss			3,212	0	0
Contributions to equity investment in investee			(2,450)	(2,290)	0
Return of equity investment in tax credit fund			600
Transfer of cash (to) from restricted accounts			(21,037)	(1,341)	(10,097)
Sale of restricted investments			0	0	11,138
Maturity of restricted investments			0	0	1,458
Other investing			622	881	2,153
Net cash (used in) provided by investing activities			(198,640)	(156,044)	(196,575)
Financing Activities [Abstract]
Draws on credit facility			15,000	63,000	157,000
Payments on credit facility			(15,000)	(83,000)	(157,000)
Issuance of long-term debt			330,000	75,000	0
Repayment of long-term debt			(326,814)	(100,824)	(14,876)
Contribution from parent			50,000	0	0
Distributions to parent			(110,000)	(135,000)	(115,000)
Other financing			(4,526)	(3,127)	(2,514)
Net cash provided by (used in) financing activities			(61,340)	(183,951)	(132,390)
Net increase (decrease) in cash and cash equivalents			(44,223)	26,543	18,107
Cash and cash equivalents at beginning of period	$ 65,705		65,705	39,162	21,055
Cash and cash equivalents at end of period		$ 21,482	21,482	65,705	39,162
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized			92,585	74,219	74,326
Income taxes (refunded) paid, net			(485)	(27)	257
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment			16,755	7,249	12,225
ARO [Member] | Cleco Power [Member]
Supplementary non-cash investing and financing activities [Abstract]
Non-cash additions to property, plant, and equipment			0	184	4,400
Coughlin [Member] | Cleco Power [Member]
Supplementary non-cash investing and financing activities [Abstract]
Non-cash additions to property, plant, and equipment			0	0	176,244
Successor [Member]
Operating Activities [Abstract]
Net (loss) income		(24,113)
Adjustments to reconcile net income to net cash provided by operating activities [Abstract]
Depreciation and amortization		141,544
Gain sale of assets		0
Provision for doubtful accounts		4,473
Unearned compensation expense		1,147
Allowance for equity funds used during construction		(3,735)
Net deferred income taxes		(21,053)
Deferred fuel costs		(8,192)
Cash surrender value of company-/trust-owned life insurance		(2,561)
Provision for merger commitments		21,964
Changes in assets and liabilities [Abstract]
Accounts receivable		(21,537)
Unbilled revenue		(837)
Fuel inventory and materials and supplies		2,880
Prepayments		(2,514)
Accounts payable		5,183
Customer deposits		7,333
Postretirement benefit obligations		3,750
Regulatory assets and liabilities, net		13,750
Other deferred accounts		(28,010)
Taxes accrued		(24,210)
Interest accrued		(11,104)
Deferred compensation		(799)
Other operating		(2,037)
Net cash provided by operating activities		51,322
Investing Activities [Abstract]
Additions to property, plant, and equipment		(144,444)
Allowance for equity funds used during construction		3,735
Proceeds from sale of property, plant, and equipment		766
Reimbursement for property loss		3,159
Contributions to equity investment in investee		0
Premiums paid on trust-owned life insurance		0
Return of equity investment in tax credit fund		901
Contributions to tax credit fund		0
Transfer of cash (to) from restricted accounts		(25,884)
Sale of restricted investments		0
Maturity of restricted investments		0
Other investing		622
Net cash (used in) provided by investing activities		(161,145)
Financing Activities [Abstract]
Draws on credit facility		15,000
Payments on credit facility		(15,000)
Issuance of long-term debt		1,680,000
Repayment of long-term debt		(1,668,268)
Repurchase of common stock		0
Payments of financing costs		(8,655)
Dividends paid on common stock		(572)
Contribution from parent		100,720
Distributions to parent		(88,765)
Other financing		(1,890)
Net cash provided by (used in) financing activities		12,570
Net increase (decrease) in cash and cash equivalents		(97,253)
Cash and cash equivalents at beginning of period		120,330
Cash and cash equivalents at end of period	120,330	23,077	23,077
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized		116,496
Income taxes (refunded) paid, net		4,263
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment		17,599
Successor [Member] | ARO [Member]
Supplementary non-cash investing and financing activities [Abstract]
Non-cash additions to property, plant, and equipment		0
Predecessor [Member]
Operating Activities [Abstract]
Net (loss) income	(3,960)			133,669	154,739
Adjustments to reconcile net income to net cash provided by operating activities [Abstract]
Depreciation and amortization	45,869			156,211	156,590
Gain sale of assets	(1,095)			0	(6,224)
Provision for doubtful accounts	1,212			3,464	2,994
Unearned compensation expense	3,276			6,344	6,545
Allowance for equity funds used during construction	(723)			(3,063)	(5,380)
Net deferred income taxes	2,219			74,103	63,597
Deferred fuel costs	977			9,899	(11,558)
Cash surrender value of company-/trust-owned life insurance	(840)			950	(3,616)
Provision for merger commitments	0			0	0
Changes in assets and liabilities [Abstract]
Accounts receivable	(1,865)			(13,656)	11,556
Unbilled revenue	563			4,481	(7,310)
Fuel inventory and materials and supplies	19,312			(13,698)	(12,147)
Prepayments	2,395			2,750	27
Accounts payable	8,348			(25,294)	4,481
Customer deposits	3,342			12,162	14,960
Postretirement benefit obligations	9,746			14,173	8,864
Regulatory assets and liabilities, net	5,178			18,793	(777)
Other deferred accounts	6,878			(17,454)	(14,691)
Taxes accrued	10,820			(831)	(22,685)
Interest accrued	17,909			(1,024)	(3,519)
Deferred compensation	(793)			(1,166)	332
Other operating	1,012			209	(1,609)
Net cash provided by operating activities	129,780			361,022	335,169
Investing Activities [Abstract]
Additions to property, plant, and equipment	(42,392)			(156,819)	(207,636)
Allowance for equity funds used during construction	723			3,063	5,380
Proceeds from sale of property, plant, and equipment	1,932			0	9,316
Reimbursement for property loss	53			0	191
Contributions to equity investment in investee	(2,450)			(2,290)	0
Premiums paid on trust-owned life insurance	0			(3,607)	(2,831)
Return of equity investment in tax credit fund	476			2,128	2,579
Contributions to tax credit fund	0			(9,966)	(55,315)
Transfer of cash (to) from restricted accounts	4,847			(1,341)	(10,097)
Sale of restricted investments	0			0	11,138
Maturity of restricted investments	0			0	1,458
Other investing	0			881	(697)
Net cash (used in) provided by investing activities	(36,811)			(167,951)	(246,514)
Financing Activities [Abstract]
Draws on credit facility	3,000			120,000	254,000
Payments on credit facility	(10,000)			(163,000)	(202,000)
Issuance of long-term debt	0			75,000	0
Repayment of long-term debt	(8,546)			(100,824)	(14,876)
Repurchase of common stock	0			0	(12,449)
Payments of financing costs	(43)			(693)	(71)
Dividends paid on common stock	(24,579)			(97,283)	(95,044)
Contribution from parent	0			0	0
Distributions to parent	0			0	0
Other financing	(717)			(2,448)	(2,448)
Net cash provided by (used in) financing activities	(40,885)			(169,248)	(72,888)
Net increase (decrease) in cash and cash equivalents	52,084			23,823	15,767
Cash and cash equivalents at beginning of period	68,246	$ 120,330	$ 68,246	44,423	28,656
Cash and cash equivalents at end of period	120,330			68,246	44,423
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized	2,478			74,349	74,515
Income taxes (refunded) paid, net	(481)			1,434	15,286
Supplementary non-cash investing and financing activities [Abstract]
Accrued additions to property, plant, and equipment	10,619			7,313	12,325
Predecessor [Member] | ARO [Member]
Supplementary non-cash investing and financing activities [Abstract]
Non-cash additions to property, plant, and equipment	$ 0			$ 184	$ 4,400

Consolidated Statements of Chan

Consolidated Statements of Changes in Equity - USD ($) $ in Thousands	Total	Common Stock [Member]	Member Units [Member]	Retained Earnings [Member]	AOCI [Member]	Cleco Power [Member]	Cleco Power [Member]Member's Equity [Member]	Cleco Power [Member]AOCI [Member]
Balances. Beginning (Predecessor [Member]) at Dec. 31, 2013	$ 1,586,197	$ 463,070		$ 1,149,003	$ (25,876)
Balances. Beginning at Dec. 31, 2013								$ (15,177)
Balances, Beginning at Dec. 31, 2013						$ 1,370,573	$ 1,385,750	(15,177)
Increase (Decrease) in Equity [Roll Forward]
Common stock issued for compensatory plans | Predecessor [Member]	602	602
Repurchase of common stock | Predecessor [Member]	(12,449)	(12,449)
Dividends on common stock | Predecessor [Member]	(95,030)			(95,030)
Non-cash contributions from parent						138,080	138,080
Distribution to member						(115,000)	115,000
Net (loss) income | Predecessor [Member]	154,739			154,739
Net (loss) income						154,316	154,316
Other comprehensive income (loss), net of tax | Predecessor [Member]	(6,789)				(6,789)
Other comprehensive income (loss), net of tax						(2,111)		(2,111)
Balances, Ending (Predecessor [Member]) at Dec. 31, 2014	1,627,270	451,223		1,208,712	(32,665)
Balances, Ending at Dec. 31, 2014								(17,288)
Balances, Beginning at Dec. 31, 2014						1,545,858	1,563,146	(17,288)
Increase (Decrease) in Equity [Roll Forward]
Common stock issued for compensatory plans | Predecessor [Member]	5,189	5,189
Dividends on common stock | Predecessor [Member]	(97,367)			(97,367)
Distribution to member						(135,000)	135,000
Net (loss) income | Predecessor [Member]	133,669			133,669
Net (loss) income						141,350	141,350
Other comprehensive income (loss), net of tax | Predecessor [Member]	6,080				6,080
Other comprehensive income (loss), net of tax						196		196
Balances, Ending (Predecessor [Member]) at Dec. 31, 2015	1,674,841	456,412		1,245,014	(26,585)
Balances, Ending at Dec. 31, 2015								(17,092)
Balances, Beginning at Dec. 31, 2015						1,552,404	1,569,496	(17,092)
Increase (Decrease) in Equity [Roll Forward]
Common stock issued for compensatory plans | Predecessor [Member]	(1,277)	(1,277)
Dividends on common stock | Predecessor [Member]	(24,190)			(24,190)
Net (loss) income | Predecessor [Member]	(3,960)			(3,960)
Other comprehensive income (loss), net of tax | Predecessor [Member]	647				647
Balances, Ending (Predecessor [Member]) at Apr. 12, 2016	1,646,061	455,135		1,216,864	(25,938)
Balances. Beginning (Predecessor [Member]) at Dec. 31, 2015	1,674,841	456,412		1,245,014	(26,585)
Balances. Beginning at Dec. 31, 2015								(17,092)
Balances, Beginning at Dec. 31, 2015						1,552,404	1,569,496	(17,092)
Increase (Decrease) in Equity [Roll Forward]
Distribution to member						(110,000)	(110,000)
Net (loss) income						39,128	39,128
Other comprehensive income (loss), net of tax						3,670		3,670
Contribution from parent						50,000	50,000
Balances, Ending (Successor [Member]) at Dec. 31, 2016					1,500
Balances, Ending at Dec. 31, 2016								(13,422)
Balances, Beginning (Successor [Member]) at Dec. 31, 2016	2,046,763		$ 2,069,376	(24,113)	1,500
Balances, Beginning at Dec. 31, 2016						1,535,202	1,548,624	(13,422)
Balances. Beginning (Predecessor [Member]) at Apr. 12, 2016	1,646,061	$ 455,135		1,216,864	(25,938)
Increase (Decrease) in Equity [Roll Forward]
Net (loss) income | Successor [Member]	(24,113)
Other comprehensive income (loss), net of tax | Successor [Member]	1,500				1,500
Balances, Ending (Successor [Member]) at Dec. 31, 2016					1,500
Balances, Ending at Dec. 31, 2016								(13,422)
Balances, Beginning (Successor [Member]) at Dec. 31, 2016	2,046,763		2,069,376	(24,113)	1,500
Balances, Beginning at Dec. 31, 2016						1,535,202	1,548,624	(13,422)
Balances, Beginning (Successor [Member]) at Apr. 13, 2016	2,158,141		2,158,141	0	0
Increase (Decrease) in Equity [Roll Forward]
Distribution to member | Successor [Member]	(88,765)		(88,765)
Net (loss) income | Successor [Member]	(24,113)			(24,113)
Other comprehensive income (loss), net of tax | Successor [Member]	1,500				1,500
Balances, Ending (Successor [Member]) at Dec. 31, 2016					1,500
Balances, Ending at Dec. 31, 2016								(13,422)
Balances, Beginning (Successor [Member]) at Dec. 31, 2016	$ 2,046,763		$ 2,069,376	$ (24,113)	$ 1,500
Balances, Beginning at Dec. 31, 2016						$ 1,535,202	$ 1,548,624	$ (13,422)

Consolidated Statements of Cha9

Consolidated Statements of Changes in Equity (Parenthetical) - Predecessor [Member] - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Dividends on common stock (in dollars per share)	$ 0.40	$ 1.60	$ 1.5625
Common Stock, Value, Issued	$ 61.1	$ 61.1	$ 61.1
Premium on common stock	414.6	418.5	415.5
Treasury Stock, Value	$ 20.5	$ 23.2	$ 25.3

The Company

The Company	12 Months Ended
	Dec. 31, 2016
Organization, Consolidation and Presentation of Financial Statements [Abstract]
The Company	Note 1 — The Company General Cleco Holdings is a holding company composed of the following: • Cleco Power, a regulated electric utility subsidiary, which 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. Cleco Power also owns a 50 % interest in an entity that owns lignite reserves. Cleco Power owns all of the outstanding membership interests in Cleco Katrina/Rita, a special purpose entity that is consolidated with Cleco Power in its financial statements. • Midstream is a wholesale energy subsidiary, regulated by FERC, which owns Evangeline. Prior to March 15, 2014, Evangeline owned Coughlin and its two generating units with a total nameplate capacity of 775 MW. On March 15, 2014, Coughlin was transferred from Evangeline to Cleco Power. • Cleco’s other operations consist of a holding company, two transmission interconnection facility subsidiaries, a shared services subsidiary, and an investment subsidiary. 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. As a result, Cleco Corporation is presented as the predecessor entity and Cleco Holdings is presented as the successor entity. For more information on the Merger, see Note 3 — “Business Combinations.”

Summary of Significant Accounti

Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Summary of Significant Accounting Policies	Note 2 — Summary of Significant Accounting Policies Use of Estimates The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates. Principles of Consolidation The accompanying consolidated financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions. Goodwill Goodwill is the excess of the purchase price (consideration transferred and liabilities assumed) over the estimated fair value of net assets of the acquired business and is not subject to amortization. Goodwill will be assessed annually or more often if an event occurs or circumstances change that would indicate the carrying amount may be impaired. If the fair value of Cleco is less than the carrying value, a full valuation of Cleco’s assets and liabilities, conducted as though Cleco were a newly acquired business, would occur. For more information on goodwill, see Note 17 — “Intangible Assets and Goodwill.” Intangible Assets Intangible assets include Cleco Katrina/Rita’s right to bill and collect storm recovery charges, fair value adjustments for long-term wholesale power supply agreements, and a fair value adjustment for the valuation of the Cleco trade name. The intangible assets are being amortized over their estimated useful lives in a manner that best reflects the economic benefits derived from such assets. Impairment will be tested if there are events or circumstances that indicate that an impairment analysis should be performed. If such an event or circumstance occurs, intangible impairment testing will be performed prior to goodwill impairment testing. Impairment is calculated as the excess of the asset’s carrying amount over its fair value. For more information on intangible assets, see Note 17 — “Intangible Assets and Goodwill.” Statements of Cash Flows Cleco and Cleco Power’s Consolidated Statements of Cash Flows are prepared using the indirect method. This method requires adjusting net income to remove the effects of all deferrals and accruals of operating cash receipts and payments and to remove items whose cash effects are related to investing and financing cash flows. Derivatives meeting the definition of an accounting hedge are classified in the same category as the item being hedged. Regulation Cleco Power is subject to regulation by FERC and the LPSC. Cleco Power complies with the accounting policies and practices prescribed by its regulatory commissions. Cleco Power’s retail rates are regulated by the LPSC and its tariffs for transmission services are regulated by FERC. Rates for wholesale power sales are based on market-based rates, pending FERC review of Cleco Power’s generation market power analysis. Cleco Power capitalizes or defers certain costs for recovery from customers and recognizes a liability for amounts expected to be returned to customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process. Regulatory assets and liabilities are amortized consistent with the treatment of the related cost in the ratemaking process. Pursuant to this regulatory approval, Cleco has recorded regulatory assets and liabilities. Any future plan adopted by the LPSC for purposes of transitioning utilities from LPSC regulation to retail competition may affect the regulatory assets and liabilities recorded by Cleco if the criteria for the application of the authoritative guidelines for industry regulated operations cannot continue to be met. At this time, Cleco cannot predict whether any legislation or regulation affecting Cleco will be enacted or adopted and, if enacted, what form such legislation or regulation may take. For more information regarding the regulatory assets and liabilities recorded by Cleco Power, see Note 4 — “Regulatory Assets and Liabilities.” AROs Cleco Power recognizes an ARO when there is a legal obligation under existing or enacted law, statute, written or oral contract, or by legal construction under the doctrine of promissory estoppel to incur costs to remove an asset when the asset is retired. These guidelines also require an ARO which is conditional on a future event to be recorded even if the event has not yet occurred. Cleco Power recognizes AROs at the present value of the projected liability in the period in which it is incurred, if a reasonable estimate of fair value can be made. The liability is then accreted to its present value each accounting period. Cleco Power defers this accretion as a regulatory asset based on its determination that these costs can be collected from customers. Concurrent with the recognition of the liability, these costs are capitalized to the related property, plant, and equipment asset. These capitalized costs are depreciated over the same period as the related property asset. Cleco Power also defers the current depreciation of the asset retirement cost as a regulatory asset. In April 2015, the EPA published the final rule in the Federal Register for regulating the disposal and management of CCRs from coal-fired power plants under Subtitle D of the Resource Conservation and Recovery Act. The Subtitle D option will regulate CCRs in a manner similar to industrial solid waste. The final rule does not require expensive synthetic lining of existing impoundments. At December 31, 2015, based on management’s best estimate of the retirement costs related to this ruling, Cleco Power recorded a $1.0 million increase to its ARO for the retirement of certain ash disposal facilities. All costs of the CCR rule are expected to be recovered from customers in future rates. The actual asset retirement costs related to the CCR rule requirements may vary substantially from the estimates used to record the increased obligation due to the uncertainty about the compliance strategies that will be used and the preliminary nature of available data used to estimate costs. Cleco Power will continue to gather additional data in future periods and will make decisions about compliance strategies and the timing of closure activities. As this additional information becomes available, Cleco Power will update the ARO balance for these changes in estimates. At December 31, 2016, management’s analysis confirmed that no additional adjustments were needed to update Cleco Power’s ARO balance. For more information on Cleco Power’s current AROs, see Note 4 — “Regulatory Assets and Liabilities — AROs.” Property, Plant, and Equipment Property, plant, and equipment consists primarily of regulated utility generation and energy transmission and distribution assets. Regulated assets, utilized primarily for retail operations and electric transmission and distribution, are stated at the cost of construction, which includes certain materials, labor, payroll taxes and benefits, administrative and general costs, and the estimated cost of funds used during construction. Jointly owned assets are reflected in property, plant, and equipment at Cleco Power’s share of the cost to construct or purchase the assets. For information on jointly owned assets, see Note 5 — “Jointly Owned Generation Units.” Most of the carrying values of Cleco’s assets 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. A fair value adjustment was made to record the stepped-up basis for the Coughlin assets, since Cleco Power is able to earn a return on and recover these costs from customers. At the date of the Merger, the gross balance of fixed depreciable assets at Cleco was adjusted to be net of accumulated depreciation, as no accumulated depreciation existed on the date of the Merger. Since pushdown accounting was not elected at the Cleco Power level, Cleco Power retained its accumulated depreciation. For more information about merger related adjustments to property, plant, and equipment, see Note 3 — “Business Combinations.” Cleco’s cost of improvements to property, plant, and equipment is capitalized. Costs associated with repairs and major maintenance projects are expensed as incurred. Cleco capitalizes the cost to purchase or develop software for internal use. The amounts of unamortized computer software costs at December 31, 2016 , and 2015 were $10.0 million and $12.5 million , respectively. Amortization of capitalized computer software costs charged to expense in Cleco and Cleco Power’s Statements of Income for the years ending December 31, 2016 , 2015 , and 2014 is shown in the following tables: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE Amortization $ 2,351 $ 921 $ 2,194 $ 1,397 Cleco Power FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Amortization $ 2,405 $ 1,718 $ 1,096 Upon retirement or disposition, the cost of Cleco Power’s depreciable plant and the cost of removal, net of salvage value, are charged to accumulated depreciation. For Cleco’s other depreciable assets, upon disposition or retirement, the difference between the net book value of the property and any proceeds received for the property is recorded as a gain or loss on asset disposition on Cleco’s Consolidated Statements of Income. Any cost incurred to remove the asset is charged to expense. Annual depreciation provisions expressed as a percentage of average depreciable property for Cleco Power for both 2016 and 2015 was 2.68% . Annual depreciation provisions expressed as a percentage of average depreciable property for Cleco Power for 2014 was 2.66% . Depreciation on property, plant, and equipment is calculated primarily on a straight-line basis over the useful lives of the assets, as follows: CATEGORY YEARS Utility Plants Production 10 – 95 Distribution 15 – 50 Transmission 5 – 55 Other utility plant 5 – 45 Other property, plant, and equipment 5 – 45 At December 31, 2016 , and 2015 , Cleco and Cleco Power’s property, plant, and equipment consisted of the following: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Utility plants Production $ 1,866,601 $ 2,385,345 Distribution 955,126 1,350,475 Transmission 503,996 665,338 Other utility plant 146,976 244,540 Other property, plant, and equipment 3,882 15,514 Total property, plant, and equipment 3,476,581 4,661,212 Accumulated depreciation (75,816 ) (1,536,158 ) Net property, plant, and equipment $ 3,400,765 $ 3,125,054 Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Regulated utility plants Production $ 2,406,572 2,385,345 Distribution 1,405,703 1,350,475 Transmission 719,052 665,338 Other utility plant 259,238 244,540 Total property, plant, and equipment 4,790,565 4,645,698 Accumulated depreciation (1,618,241 ) (1,525,298 ) Net property, plant, and equipment $ 3,172,324 $ 3,120,400 During 2016 , Cleco Power’s regulated utility property, plant, and equipment increased primarily due to the Cenla Transmission Expansion project, the Layfield/Messick project, and general rehabilitation of transmission, distribution, and generation assets. Cleco Power’s property, plant, and equipment includes plant acquisition adjustments related primarily to the acquisition of Acadia Unit 1 in 2010 and Teche in 1997. Accumulated amortization associated with the plant acquisition adjustments are reported in accumulated depreciation on Cleco Power’s Consolidated Balance Sheets. The plant acquisition adjustments and accumulated amortization reported in property, plant, and equipment and accumulated depreciation on Cleco and Cleco Power’s Consolidated Balance Sheets at December 31, 2016 , and 2015 are shown in the following tables: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Acadia Unit 1 Plant acquisition adjustment $ 76,116 $ 95,578 Accumulated amortization (2,287 ) (18,567 ) Net plant acquisition adjustment $ 73,829 $ 77,011 Teche and other Plant acquisition adjustment $ 544 $ 5,271 Accumulated amortization (183 ) (4,655 ) Net plant acquisition adjustment $ 361 $ 616 Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Acadia Unit 1 Plant acquisition adjustment $ 95,578 $ 95,578 Accumulated amortization (21,749 ) (18,567 ) Net plant acquisition adjustment $ 73,829 $ 77,011 Teche and other Plant acquisition adjustment $ 5,271 $ 5,271 Accumulated amortization (4,910 ) (4,655 ) Net plant acquisition adjustment $ 361 $ 616 Deferred Project Costs Cleco Power defers costs related to the initial stage of a construction project during which time the feasibility of the construction of property, plant, and equipment is being investigated. At December 31, 2016 , and 2015 , Cleco Power had deferred $5.0 million and $4.6 million , respectively, for projects that are in the initial stages of development. These amounts are classified as Other deferred charges on Cleco Power’s Consolidated Balance Sheets. Fuel Inventory and Materials and Supplies Fuel inventory consists primarily of petroleum coke, coal, limestone, lignite, and natural gas used to generate electricity. Materials and supplies consists of transmission and distribution line construction and repair materials. It also consists of generating station and transmission and distribution substation repair materials. Both fuel inventory and materials and supplies are stated at average cost and are issued from stock using the average cost of existing stock. Materials and supplies are recorded when purchased and subsequently charged to expense or capitalized to property, plant, and equipment when installed. Accounts Receivable Accounts receivable are recorded at the invoiced amount and do not bear interest. It is the policy of management to review the outstanding accounts receivable monthly, as well as the bad debt write-offs experienced in the past, and establish an allowance for doubtful accounts. Account balances are charged off against the allowance when management determines it is probable the receivable will not be recovered. At December 31, 2016 , and 2015 , the balance of the allowance for doubtful accounts was $7.2 million and $2.7 million , respectively. The increase in allowance for doubtful accounts is primarily due to a reserve related to a potential industrial customer. There was no off-balance sheet credit exposure related to Cleco’s customers. Financing Receivables At December 31, 2016 , Cleco, through Perryville and Attala, had a combined net investment in direct financing lease long-term assets of $13.5 million . The net investment at December 31, 2015 , was also $13.5 million . Each subsidiary leases its respective transmission assets to a single counterparty. Both counterparties are considered credit worthy and are expected to pay their obligations when due, thus, no allowance for credit loss has been recognized. Management bases this assessment on the following common factors of each counterparty: • both counterparties use the respective transmission facilities to move electricity from its power plants to the regional transmission grid, • neither counterparty has another avenue to move electricity from its respective power plants to the regional transmission grid, • the stream of payments was approved by FERC through respective rate orders, and • both counterparties serve retail and wholesale customers in their respective service territories under LPSC oversight that allows recovery of prudent costs, of which, the stream of payments under the direct financing leases appear to be prudent. Management monitors both entities for indication of adverse actions by their respective public service commissions and market conditions which would indicate an inability to pay their obligations under the direct financing leases when due. Since the inception of the agreements, each counterparty has paid their respective obligations when due, and at December 31, 2016 , and 2015 , no amounts were past due. Reserves Cleco maintains property insurance on generating stations, buildings and contents, and substations. Cleco is self-insured for any damage to transmission and distribution lines. To mitigate the exposure to potential financial loss for damage to lines, Cleco maintains an LPSC-approved funded storm reserve. Cleco Power also maintains liability and workers’ compensation insurance to mitigate financial losses due to injuries and damages to the property of others. Cleco’s insurance covers claims that exceed certain self-insured limits. For claims that do not meet the limits to be covered by insurance, Cleco Power maintains reserves. At December 31, 2016 , and 2015 , the general liability and workers compensation reserves together were $4.6 million and $5.5 million , respectively. Additionally, Cleco maintains directors and officers insurance to protect managers from claims which may arise from their decisions and actions taken within the scope of their regular duties. Cash Equivalents Cleco considers highly liquid, marketable securities, and other similar instruments with original maturity dates of three months or less to be cash equivalents. 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 company purposes. Cleco and Cleco Power’s restricted cash and cash equivalents consisted of: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current Cleco Katrina/Rita’s storm recovery bonds $ 9,213 $ 9,263 Cleco Power’s charitable contributions 1,200 — Cleco Power’s rate credit escrow 12,671 — Total current 23,084 9,263 Non-current Diversified Lands’ mitigation escrow 21 21 Cleco Power’s future storm restoration costs 17,379 16,174 Cleco Power’s charitable contributions 4,179 — Cleco Power’s rate credit escrow 1,831 — Total non-current 23,410 16,195 Total restricted cash and cash equivalents $ 46,494 $ 25,458 Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current Cleco Katrina/Rita’s storm recovery bonds $ 9,213 $ 9,263 Charitable contributions 1,200 — Rate credit escrow 12,671 — Total current 23,084 9,263 Non-current Future storm restoration costs 17,379 16,174 Charitable contributions 4,179 — Rate credit escrow 1,831 — Total non-current 23,389 16,174 Total restricted cash and cash equivalents $ 46,473 $ 25,437 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, 2015 , to 2016 was due to Cleco Katrina/Rita collecting $21.2 million net of administration fees, partially offset by bond and interest payments. In March and September 2016 , Cleco Katrina/Rita used $8.5 million and $8.3 million , respectively, for scheduled storm recovery bond principal payments and $2.3 million and $2.1 million , respectively, for related interest payments. 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 December 31, 2016 , $0.6 million of the charitable contributions and $121.5 million of the rate credits had been remitted from restricted cash. Equity Investments Cleco and Cleco Power account for investments in unconsolidated affiliated companies using the equity method of accounting. The amounts reported on Cleco and Cleco Power’s Consolidated Balance Sheets represent assets contributed by Cleco or Cleco Power, plus their share of the net income of the affiliate, less any distributions of earnings (dividends) received from the affiliate. The revenues and expenses (excluding income taxes) of these affiliates are netted and reported on one line item as equity income from investees on Cleco and Cleco Power’s Consolidated Statements of Income. Cleco evaluates for impairments of equity method investments at each balance sheet date to determine if events and circumstances have occurred that indicate a possible other-than-temporary decline in the fair value of the investment and the possible inability to recover the carrying value through operations. Cleco uses estimates of the future cash flows from the investee and observable market transactions in order to calculate fair value and recoverability. An impairment is recognized when an other-than-temporary decline in market value occurs and recovery of the carrying value is not probable. There were no impairments recorded for 2016 , 2015 , or 2014 . For more information on Cleco’s equity investments, see Note 13 — “Variable Interest Entities.” Income Taxes Cleco accounts for income taxes under the asset and liability method. Cleco provides for federal and state income taxes currently payable, as well as for those deferred due to timing differences between reporting income and expenses for financial statement purposes versus tax purposes. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using enacted income tax rates expected to be applied to taxable income in the years in which those temporary differences are expected to be recovered or settled. Deferred tax assets and liabilities are classified as non-current on Cleco and Cleco Power’s Consolidated Balance Sheets. Cleco’s income tax expense and related regulatory assets and liabilities could be affected by changes in its assumptions and estimates and by ultimate resolution of assumptions and estimates with taxing authorities. Cleco files a federal income tax return for all wholly owned subsidiaries. Cleco Power computes its federal and state income taxes as if it were a stand-alone taxpayer. The LPSC generally requires Cleco Power to flow the effects of state income taxes to customers immediately. The LPSC specifically requires that the state tax benefits associated with the deductions related to certain storm damages be normalized. For more information on income taxes, see Note 10 — “Income Taxes.” Investment Tax Credits Investment tax credits, which were deferred for financial statement purposes, are amortized as a reduction to income tax expense over the estimated service lives of the properties that gave rise to the credits. NMTC Fund In 2008, Cleco Holdings and US Bancorp Community Development Corporation (USBCDC) formed the NMTC Fund. 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 gross investment amortization expense of the NMTC Fund will be recognized over a over a ten -year period, with two years remaining under the new amendment, using the cost method. The grants received under Section 1603, which allow certain projects to receive a federal grant in lieu of tax credits, and other cash reduce the basis of the investment. Periodic amortization of the investment and the deferred taxes generated by the basis reduction temporary difference are included as components of income tax expense. For more information, see Note 15 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — NMTC Fund.” Accounting for Renewable Energy Tax Credits and Grants Under the ARRA Cleco and the NMTC Fund have elected to receive cash grants under the ARRA for investments in various projects. Cleco has elected to reduce the carrying value of the qualifying assets as cash grants are received, which will reduce the amount of depreciation expense recognized after the underlying assets are placed in service. Certain cash grants also reduce the tax basis of the underlying assets. Grants received via the NMTC Fund reduce the carrying value of the investment for GAAP, but do not reduce the income tax basis of the investment. Debt Issuance Costs, Premiums, and Discounts Issuance costs, premiums, and discounts applicable to debt securities are amortized to interest expense ratably over the lives of the related issuances. Expenses and call premiums related to refinanced Cleco Power debt are deferred and amortized over the life of the new issuance. Debt issuance costs, premiums, and discounts are presented as a direct deduction from the carrying value of the related debt liability. Revenue and Fuel Costs Utility Revenue Revenue from sales of electricity is recognized when the service is provided. The costs of fuel and purchased power used for retail customers currently are recovered from customers through the FAC. These costs are subject to audit and final determination by regulators. Excise taxes and pass-through fees collected on the sale of electricity are not recorded in utility revenue. Unbilled Revenue Cleco Power accrues estimated revenue monthly for energy used by customers but not yet billed. The monthly estimated unbilled revenue amounts are recorded as unbilled revenue and a receivable. During the third quarter of 2014, Cleco Power began using actual customer energy consumption data available from AMI to calculate unbilled revenues. Other Operations Revenue Other operations revenue is recognized at the time products or services are provided to and accepted by customers, and collectability is reasonably assured. Sales/Excise Taxes Cleco Power collects a sales and use tax on the sale of electricity that subsequently is remitted to the state in accordance with state law. These amounts are not recorded as income or expense on Cleco’s Consolidated Statements of Income but are reflected at gross amounts on Cleco’s Consolidated Balance Sheets as a receivable until the tax is collected and as a payable until the liability is paid. Cleco currently does not have any excise taxes reflected on its income statement. Franchise Fees Cleco Power collects a consumer fee for one of its franchise agreements. This fee is not recorded on Cleco’s Consolidated Statements of Income as revenue and expense, but is reflected at gross amounts on Cleco’s Consolidated Balance Sheets as a receivable until it is collected and as a payable until the liability is paid. AFUDC The capitalization of AFUDC by Cleco Power is a utility accounting practice prescribed by FERC and the LPSC. AFUDC represents the estimated debt and equity costs of capital funds that are necessary to finance construction of new and existing facilities. While cash is not realized currently from such allowance, AFUDC increases the revenue requirement over the same life of the plant through a higher rate base and higher depreciation. Under regulatory practices, a return on and recovery of AFUDC is permitted in setting rates charged for utility services. The composite AFUDC rate, including borrowed and other funds, was 11.94% on a pretax basis ( 7.39% net of tax) for 2016 , 11.46% on a pretax basis ( 7.09% net of tax) for 2015 , and 10.46% on a pretax basis ( 6.47% net of tax) for 2014 . 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 6 — “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 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 in the second half of 2017. There were no open natural gas positions at December 31, 2016 , or 2015 . 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 Consolidated Balance Sheets. Realized gains or losses on settled FTRs are recorded in Fuel used for electric generation on Cleco Power’s Consolidated Statements of Income. At December 31, 2016 , Cleco Power’s Consolidated Balance Sheets reflected the fair value of open FTR positions of $7.9 million in Energy risk management assets and $0.2 million in Energy risk management liabilities, compared to $7.7 million in Energy risk management assets and $0.3 million in Energy risk management liabilities at December 31, 2015 . For more information on FTRs, see Note 6 — “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 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 years ende

Business Combinations

Business Combinations	12 Months Ended
	Dec. 31, 2016
Business Combinations [Abstract]
Business Combinations	Note 3 — 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. At the effective time of the Merger, each outstanding share of Cleco Corporation common stock, par value $1.00 per share (other than shares that were owned by Cleco Corporation, Cleco Partners, Merger Sub, or any other direct or indirect wholly owned subsidiary of Cleco Partners or Cleco Corporation), were cancelled and 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. 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, and are included in Merger transaction and commitment costs and Merger commitment costs on Cleco and Cleco Power’s Consolidated Statements of Income, respectively. 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 12 — “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 tables present 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 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 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 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 Consolidated Balance Sheet to reflect the valuation of the Cleco trade name. This adjustment is included in Intangible assets on Cleco’s 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 Consolidated Statement of Income. On the date of the Merger, fair value adjustments were recorded on Cleco’s 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 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 will be amortized over the remaining term of the applicable contract. The amortization of the power supply agreements is included in Electric operations on Cleco’s Consolidated Statement of Income. The net increase in deferred tax liabilities on Cleco’s 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. For more information, see Note 4 — “Regulatory Assets and Liabilities.” 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. Accounting guidance provides that the allocation of the purchase price may be modified up to one year from the date of the Merger, as more information is obtained about the fair value of assets acquired and liabilities assumed. The preliminary amounts recognized are subject to revision until the valuations are completed and to the extent that additional information is obtained about the facts and circumstances that existed as of the date of the Merger. Except for the effects of the positions related to the Merger reflected on income tax returns, Cleco completed its evaluation and determination of the fair value of certain assets and liabilities acquired as of December 31, 2016. While management believes the positions reflected on the income tax returns are reasonable, the returns have not been audited by the applicable taxing authorities.

Regulatory Assets and Liabiliti

Regulatory Assets and Liabilities	12 Months Ended
	Dec. 31, 2016
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 of regulated operations. The following table summarizes Cleco Power’s net regulatory assets and liabilities: Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 REMAINING RECOVERY PERIOD Total federal regulatory (liability) asset — income taxes $ (635 ) $ 5,614 Total state regulatory asset — income taxes 112,751 105,868 AFUDC 126,335 127,092 Total investment tax credit (1,002 ) (1,633 ) Total regulatory assets — deferred taxes, net 237,449 236,941 * Mining costs 6,372 8,921 2.5 yrs. Interest costs 4,860 5,221 * AROs (1) 2,096 2,462 * Postretirement costs (1) 145,268 150,274 * Tree trimming costs 5,549 6,318 * Training costs 6,708 6,863 43 yrs. Surcredits, net (2) 5,876 9,661 * Amended lignite mining agreement contingency (1) — 3,781 — AMI deferred revenue requirement 4,772 5,318 9 yrs. Production operations and maintenance expenses 13,999 12,436 * AFUDC equity gross-up (2) 70,423 71,444 * Acadia Unit 1 acquisition costs 2,442 2,548 23 yrs. Financing costs 8,663 9,032 * Biomass costs 18 50 0.5 yrs. MISO integration costs 1,404 2,340 1.5 yrs. Coughlin transaction costs 999 1,030 32.5 yrs. Corporate franchise tax 1,308 373 * Acadia FRP true-up — 377 — MATS Costs 4,270 — 1.5 yrs Other 710 357 * Total regulatory assets 285,737 298,806 PPA true-up — (312 ) — Fuel and purchased power 20,787 12,910 * Total regulatory assets, net $ 543,973 $ 548,345 (1) Represents regulatory assets in which cash has not yet been expended and the assets are offset by liabilities that do not incur a carrying cost. (2) Represents regulatory assets for past expenditures that were not earning a return on investment at December 31, 2016. All other assets are earning a return on investment. * For information related to the remaining recovery periods, refer to the following disclosures for each specific regulatory asset. The following table summarizes Cleco’s net regulatory assets and liabilities: Cleco SUCCESSOR (1) PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Total Cleco Power regulatory assets, net $ 543,973 $ 548,345 Cleco Holdings’ Merger adjustments Fair value of long-term debt 155,776 — Postretirement costs 23,362 — Financing costs 8,966 — Debt issuance costs 7,606 — Total Cleco regulatory assets, net $ 739,683 $ 548,345 (1) Cleco Holdings’ regulatory assets include acquisition accounting adjustments as a result of the Merger. Income Taxes The regulatory asset recorded for deferred income taxes represents the effect of tax benefits or detriments that must be flowed through to customers as they are received or paid. The amounts deferred are attributable to differences between book and tax recovery periods. Mining Costs Cleco Power operates a generating unit jointly owned with SWEPCO that uses lignite as its primary fuel source. Cleco Power, along with SWEPCO, maintains a lignite mining agreement with DHLC, the operator of the Dolet Hills Mine. As ordered by the LPSC, Cleco Power’s retail customers began receiving fuel cost savings through the year 2011 while actual mining costs incurred above a certain percentage of the benchmark price were deferred, and could be recovered from retail customers through the FAC only when the actual mining costs are below a certain percentage of the benchmark price. In 2006, Cleco Power recognized that there was a possibility it may not recover all or part of the lignite mining costs it had deferred and sought relief from the LPSC. In December 2007, the LPSC approved a settlement agreement between Cleco Power, SWEPCO, and the LPSC Staff authorizing Cleco Power to recover the existing deferred mining cost balance, including interest, over 11.5 years. In connection with its approval of the Oxbow Lignite Mine acquisition, in 2009, the LPSC agreed to discontinue benchmarking and the corresponding potential to defer future lignite mining costs while preserving the recovery of the legacy deferred fuel balance previously authorized. Interest Costs Cleco Power’s deferred interest costs include additional deferred capital construction financing costs authorized by the LPSC. These costs are being amortized over the estimated lives of the respective assets constructed. AROs Cleco Power has recorded an ARO liability for the retirement of certain ash disposal facilities. The ARO regulatory asset represents the accretion of the ARO liability and the depreciation of the related assets. For more information on the accounting treatment of Cleco Power’s AROs, see Note 2 — “Summary of Significant Accounting Policies — AROs.” Postretirement Costs Cleco Power recognizes the funded status of its postretirement benefit plans as a net liability or asset. The net liability or asset is defined as the difference between the benefit obligation and the fair market value of plan assets. For defined benefit pension plans, the benefit obligation is the projected benefit obligation. Historically, the LPSC has allowed Cleco Power to recover pension plan expense. Cleco Power, therefore, recognizes a regulatory asset based on its determination that these costs can be collected from customers. These costs are amortized to pension expense over the average service life of the remaining plan participants (approximately 10 years as of December 31, 2016, for Cleco’s plan) when it exceeds certain thresholds. The amount and timing of the recovery will be based on the changing funded status of the pension plan in future periods. For more information on Cleco’s pension plan and adoption of these authoritative guidelines, see Note 9 — “Pension Plan and Employee Benefits.” Tree Trimming Costs In 2008, the LPSC approved Cleco Power’s request to establish a regulatory asset for costs incurred to trim, cut, or remove trees that were damaged by Hurricanes Katrina and Rita, but were not addressed as part of the restoration efforts. Cleco Power was allowed to recover these expenditures and the regulatory asset for the initial tree trimming project was completely amortized in January 2015. In April 2013, the LPSC approved Cleco Power’s request to expend and defer up to $8.0 million in additional tree management costs. Cleco Power requested similar accounting treatment as authorized in the initial tree extraction request and requested authorization to defer actual expenditures as a regulatory asset through the completion date of the tree extraction effort. In February 2015, Cleco Power completed the tree extraction and began amortizing the additional charges over a 3.5 -year period. As a result of increased vegetation growth and to remain in compliance with regulatory requirements, Cleco Power anticipates the need to spend $20.8 million through December 2020 in tree and vegetation management costs. In September 2016, Cleco Power requested approval from the LPSC to defer a portion of these costs utilizing the same accounting treatment of similar costs approved in previous dockets. In October 2016, the LPSC approved Cleco Power to defer an additional amount up to $10.9 million . Of the remaining costs, $4.0 million will be expensed to Maintenance on Cleco Power’s Consolidated Statements of Income, and $5.9 million will be deferred and recovered in current base rates through June 2020. Training Costs In February 2008, the LPSC approved Cleco Power’s request to establish a regulatory asset for training costs associated with existing processes and technology for new employees at Madison Unit 3. Recovery of these expenditures was approved by the LPSC in October 2009. In February 2010, Cleco Power began amortizing the regulatory asset over a 50 -year period. Surcredits, Net Cleco Power has recorded surcredits as the result of a settlement with the LPSC that addressed, among other things, the recovery of the storm damages related to hurricanes and uncertain tax positions. In the settlement, Cleco Power was required to implement surcredits to provide ratepayers with the economic benefit of the carrying charges of certain accumulated deferred income tax liabilities at a rate of return which was set by the LPSC. The settlement, through a true-up mechanism, allows the surcredits to be adjusted to reflect the actual tax deductions allowed by the IRS. Cleco Power also was allowed to record a corresponding regulatory asset in an amount representing the flow back of the carrying charges to ratepayers. This amount is being amortized over various terms of the established surcredits. In the third quarter of 2013 and the first quarter of 2014, Cleco Power recorded a true-up to the surcredits to reflect the actual tax deductions allowed by the IRS for storm damages and uncertain tax positions. As a result of the true-ups, Cleco Power has recorded a regulatory asset that represents excess surcredits refunded to customers that will be collected from ratepayers in future periods. These amounts are being collected and amortized over a four -year period. As a result of a settlement with the LPSC, Cleco Power is required to implement a surcredit when funds are withdrawn from the restricted storm reserve. In March 2014, Cleco Power withdrew $4.0 million from the restricted storm reserve to pay for storm damages, resulting in the establishment of a new surcredit. This surcredit will be utilized to partially replenish the storm reserve. These amounts are being collected and amortized over a four -year period. In June 2014, the LPSC approved Cleco Power’s FRP extension. A provision of the FRP extension was to reduce base rates by the amount of the surcredits beginning in July 2014. For more information on the FRP extension, see Note 12 — “Regulation and Rates.” Amended Lignite Mining Agreement Contingency In April 2009, Cleco Power and SWEPCO entered into a series of transactions to acquire additional lignite reserves and mining equipment from the North American Coal Corporation (NAC), each agreeing to purchase a 50% ownership interest in Oxbow from NAC for a combined price of $25.7 million . Cleco Power, SWEPCO, and DHLC entered into the Amended Lignite Mining Agreement which requires DHLC to mine lignite at the existing Dolet Hills Mine along with the Oxbow Mine and deliver the lignite to the Dolet Hills Power Station at cost plus a specified management fee. The mining areas are expected to be sufficient to provide the Dolet Hills Power Station with lignite fuel until at least 2036. Among the provisions of the Amended Lignite Mining Agreement is a requirement that if DHLC is unable to pay for loans and lease payments when due, Cleco Power will pay 50% of the amounts due. Any payments under this provision will be considered a prepayment of lignite to be delivered in the future and will be credited to future invoices from DHLC. This provision meets the recognition requirements as a guarantee to an unrelated third party. Previously, Cleco Power recorded a liability of $3.8 million with an offsetting regulatory asset due to Cleco Power’s ability to recover prudent fuel costs from customers through the FAC. Management determined that it does not expect to be required to pay DHLC under this guarantee. As a result of this determination, the liability and the offsetting regulatory asset were remeasured to zero during the second quarter of 2016. AMI Deferred Revenue Requirement In February 2011, the LPSC approved Cleco Power’s stipulated settlement in Docket No. U-31393 allowing Cleco Power to defer, as a regulatory asset, the estimated revenue requirements for the AMI project. The amount of the regulatory asset, including carrying charges, is capped by the LPSC at $20.0 million . In June 2014, the LPSC approved Cleco Power’s FRP extension and the AMI regulatory asset and project capital costs were included in rate base. Cleco Power is recovering the AMI deferred revenue requirement over 11 years beginning July 2014. Production Operations and Maintenance Expenses In September 2009, the LPSC authorized Cleco Power to defer, as a regulatory asset, production operations and maintenance expenses, net of fuel and payroll, above the retail jurisdictional portion of $25.6 million annually (deferral threshold). On June 18, 2014, the LPSC approved Cleco Power’s FRP extension, which increased the operations and maintenance deferral threshold to $45.0 million annually. The amount of the regulatory asset is capped at $23.0 million . Also, as part of the FRP extension, the LPSC allowed Cleco Power to recover the amount deferred in any calendar year over the following three year regulatory period, beginning on July 1, when the annual rates are set. In December 2013, 2014, 2015, and 2016, Cleco Power deferred $8.5 million , $7.7 million , $1.8 million , and $7.3 million , respectively, as a regulatory asset. AFUDC Equity Gross-Up Cleco Power capitalizes equity AFUDC as a cost component of construction projects. Cleco Power has recorded a regulatory asset to recover the tax gross-up related to the equity component of AFUDC. These costs are being amortized over the estimated lives of the respective assets constructed. Acadia Unit 1 Acquisition Costs In October 2009, the LPSC approved Cleco Power’s request to establish a regulatory asset for costs incurred as a result of the acquisition by Cleco Power of Acadia Unit 1 and half of Acadia Power Station’s related common facilities. The Acadia Unit 1 acquisition costs are being recovered over a 30 -year period beginning February 2010. Financing Costs In 2011, Cleco Power entered into and settled two treasury rate locks. Of the $26.8 million in settlements, $7.4 million was deferred as a regulatory asset relating to ineffectiveness of the hedge relationships. Also in 2011, Cleco Power entered into a forward starting swap contract. These derivatives were entered into in order to mitigate the interest rate exposure on coupon payments related to forecasted debt issuances. In May 2013, the forward starting interest rate swap was settled at a loss of $3.3 million . Cleco Power deferred $2.9 million of the losses as a regulatory asset, which is being amortized over the terms of the related debt issuances. Biomass Costs In November 2011, the LPSC approved Cleco Power’s request to establish a regulatory asset for the non-fuel, non-capital portion of costs incurred to conduct a test burn of biomass fuel at Madison Unit 3. In August 2012, Cleco Power began amortizing these costs over a five -year period. MISO Integration Costs In June 2014, the LPSC approved Cleco Power’s request to recover the non-capital integration costs associated with Cleco Power joining MISO. The MISO integration costs are being recovered over a four -year period beginning July 2014. Coughlin Transaction Costs In January 2014, the LPSC authorized Cleco Power to create a regulatory asset for the Coughlin transfer transaction costs. The Coughlin transaction costs are being recovered over a 35 -year period beginning July 2014. Corporate Franchise Tax As part of the FRP extension approved by the LPSC in June 2014, Cleco Power was authorized to recover through a rider the retail portion of state corporate franchise taxes paid. In 2016 and 2015, Cleco Power’s net retail portion of franchise taxes paid was $2.5 million and $1.7 million , respectively. The retail portion of state corporate franchise taxes paid each year will be recovered over 12 months beginning July 1 of the following year. Acadia FRP True-up For the FRP period July 1, 2013 through June 30, 2014, Cleco Power was authorized by the LPSC to recover the estimated revenue requirement of $58.3 million related to Acadia Unit 1. In June 2014, Cleco Power determined that it had under-recovered $0.8 million in revenue from customers based on the actual revenue requirement for Acadia Unit 1. The amount representing the under-collection was deferred and was recovered from customers over 12 months beginning July 1, 2015. MATS Costs On February 1, 2016, the LPSC approved Cleco Power’s request to recover the revenue requirements associated with the installation of MATS equipment. The MATS rule required affected EGUs to meet specific emission standards and work practice standards to address hazardous air pollutants by April 2015. The LPSC approval also allowed Cleco Power to record a regulatory asset of $7.1 million representing the unrecovered revenue requirements of MATS equipment placed in service in the years prior to the LPSC review and approval. This amount is being amortized over three years beginning January 1, 2016. Other In June 2014, the LPSC approved Cleco Power’s FRP extension which authorized the recovery of previously deferred costs incurred as a result of Cleco Power’s FRP extension filing, the 2003 through 2008 fuel audit, and a biomass study. These costs are being recovered over a three -year period beginning July 2014. In October 2015, the LPSC approved the recovery of costs incurred as a result of Cleco Power’s 2009 through 2013 fuel audit. In April 2016, the LPSC approved the recovery of costs incurred as part of Cleco Power’s IRP report filed under the IRP Order No. R-30021. Both the 2009 through 2013 fuel audit costs and the IRP costs are being recovered over a three -year period beginning July 2016. PPA True-up In preparing the FRP monitoring report for the year ended June 30, 2014, Cleco Power determined it had recovered $0.6 million above the actual PPA capacity costs. Cleco Power recorded the overcollection as a regulatory liability and returned this amount to the customers over 12 months beginning July 1, 2015. Fuel and Purchased Power The cost of fuel used for electric generation and power purchased for utility customers are recovered through the LPSC-established FAC or related wholesale contract provisions, which enable Cleco Power to pass on to its customers substantially all such charges. For 2016 , approximately 75% of Cleco Power’s total fuel cost was regulated by the LPSC. Fuel and purchased power increased $7.9 million from December 31, 2015. Of this amount, $11.5 million was due to an increase caused by surcharge adjustments, increased environmental expenses, and timing of collections. This was partially offset by a $3.6 million decrease in the mark-to-market value on FTRs. 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.

Jointly Owned Generation Units

Jointly Owned Generation Units	12 Months Ended
	Dec. 31, 2016
Regulated Operations [Abstract]
Jointly Owned Generation Units	Note 5 — Jointly Owned Generation Units Cleco Power operates electric generation units that are jointly owned with other utilities. The joint-owners are responsible for their own share of the capital and the operating and maintenance costs of the respective units. Cleco Power’s share of the direct expenses of the jointly owned generation units is included in the operating expenses of the consolidated statements of income. At the date of the Merger, the gross balance of jointly owned generation units at Cleco was adjusted to be net of accumulated depreciation, as no accumulated depreciation existed on the date of the Merger. Since pushdown accounting was not elected at the Cleco Power level, Cleco Power retained its accumulated depreciation. For more information about merger related adjustments, see Note 3 — “Business Combinations.” At December 31, 2016 , the investment in and accumulated depreciation for each generating unit on Cleco and Cleco Power’s Consolidated Balance Sheets were as follows: Cleco SUCCESSOR AT DEC. 31, 2016 (THOUSANDS, EXCEPT PERCENTAGES AND MW) RODEMACHER UNIT 2 DOLET HILLS TOTAL Utility plant in service $ 70,136 $ 177,201 $ 247,337 Accumulated depreciation $ 1,530 $ 5,783 $ 7,313 Construction work in progress $ 166 $ 3,193 $ 3,359 Ownership interest percentage 30 % 50 % Nameplate capacity (MW) 523 650 Ownership interest (MW) 157 325 Cleco Power AT DEC. 31, 2016 (THOUSANDS, EXCEPT PERCENTAGES AND MW) RODEMACHER UNIT 2 DOLET HILLS TOTAL Utility plant in service $ 144,316 $ 394,698 $ 539,014 Accumulated depreciation $ 75,710 $ 223,280 $ 298,990 Construction work in progress $ 166 $ 3,193 $ 3,359 Ownership interest percentage 30 % 50 % Nameplate capacity (MW) 523 650 Ownership interest (MW) 157 325

Fair Value Accounting

Fair Value Accounting	12 Months Ended
	Dec. 31, 2016
Fair Value Disclosures [Abstract]
Fair Value Accounting	Note 6 — Fair Value Accounting The amounts reflected in Cleco and Cleco Power’s Consolidated Balance Sheets at December 31, 2016 , and December 31, 2015 , 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 in Cleco and Cleco Power’s Consolidated Balance Sheets: Cleco SUCCESSOR PREDECESSOR AT DEC. 31, 2016 AT DEC. 31, 2015 (THOUSANDS) CARRYING VALUE* ESTIMATED FAIR VALUE CARRYING VALUE* ESTIMATED FAIR VALUE Long-term debt $ 2,768,149 $ 2,754,518 $ 1,299,529 $ 1,463,989 * The carrying value of long-term debt does not include deferred issuance costs of $11.7 million in 2016 and $9.9 million in 2015. Cleco Power AT DEC. 31, 2016 AT DEC. 31, 2015 (THOUSANDS) CARRYING VALUE* ESTIMATED FAIR VALUE CARRYING VALUE* ESTIMATED FAIR VALUE Long-term debt $ 1,262,373 $ 1,418,693 $ 1,265,529 $ 1,429,989 * The carrying value of long-term debt does not include deferred issuance costs of $9.4 million in 2016 and $9.6 million in 2015. Fair Value Measurements and Disclosures Cleco classifies assets and liabilities that are either measured or disclosed 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 or disclosed on a recurring basis: Cleco CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING: SUCCESSOR PREDECESSOR (THOUSANDS) 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) AT DEC. 31, 2015 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 $ 66,410 $ — $ 66,410 $ — $ 89,584 $ — $ 89,584 $ — FTRs 7,884 — — 7,884 7,673 — — 7,673 Total assets $ 74,294 $ — $ 66,410 $ 7,884 $ 97,257 $ — $ 89,584 $ 7,673 Liability Description Long-term debt $ 2,754,518 $ — $ 2,754,518 $ — $ 1,463,989 $ — $ 1,463,989 $ — FTRs 201 — — 201 275 — — 275 Total liabilities $ 2,754,719 $ — $ 2,754,518 $ 201 $ 1,464,264 $ — $ 1,463,989 $ 275 Cleco Power CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING: (THOUSANDS) 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) AT DEC. 31, 2015 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 $ 65,089 $ — $ 65,089 $ — $ 87,363 $ — $ 87,363 $ — FTRs 7,884 — — 7,884 7,673 — — 7,673 Total assets $ 72,973 $ — $ 65,089 $ 7,884 $ 95,036 $ — $ 87,363 $ 7,673 Liability Description Long-term debt $ 1,418,693 $ — $ 1,418,693 $ — $ 1,429,989 $ — $ 1,429,989 $ — FTRs 201 — — 201 275 — — 275 Total liabilities $ 1,418,894 $ — $ 1,418,693 $ 201 $ 1,430,264 $ — $ 1,429,989 $ 275 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: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE Beginning balance $ 3,458 $ 7,398 $ 9,949 Unrealized gains (losses)* 3,119 (1,031 ) (1,476 ) Purchases 12,896 2,070 20,319 Settlements (11,790 ) (4,979 ) (21,394 ) Ending balance $ 7,683 $ 3,458 $ 7,398 * Unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco and Cleco Power's Consolidated Balance Sheets. Cleco Power FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 Beginning balance $ 7,398 $ 9,949 Unrealized gains (losses)* 2,088 (1,476 ) Purchases 14,966 20,319 Settlements (16,769 ) (21,394 ) Ending balance $ 7,683 $ 7,398 * Unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco and Cleco Power's Consolidated Balance Sheets. The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions as of December 31, 2016 : Cleco FAIR VALUE VALUATION TECHNIQUE SIGNIFICANT UNOBSERVABLE INPUTS FORWARD PRICE RANGE (THOUSANDS, EXCEPT DOLLAR PER MWh) Assets Liabilities Low High SUCCESSOR FTRs at December 31, 2016 $ 7,884 $ 201 RTO auction pricing FTR price - per MWh $ (3.61 ) $ 6.04 PREDECESSOR FTRs at December 31, 2015 $ 7,673 $ 275 RTO auction pricing FTR price - per MWh $ (3.63 ) $ 4.51 Cleco Power FAIR VALUE VALUATION TECHNIQUE SIGNIFICANT UNOBSERVABLE INPUTS FORWARD PRICE RANGE (THOUSANDS, EXCEPT DOLLAR PER MWh) Assets Liabilities Low High FTRs at December 31, 2016 $ 7,884 $ 201 RTO auction pricing FTR price - per MWh $ (3.61 ) $ 6.04 FTRs at December 31, 2015 $ 7,673 $ 275 RTO auction pricing FTR price - per MWh $ (3.63 ) $ 4.51 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 December 31, 2016 , 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 Consolidated Balance Sheets in cash and cash equivalents, current restricted cash and cash equivalents, and non-current restricted cash and cash equivalents of $20.0 million , $23.1 million , and $23.3 million , respectively, at December 31, 2016 , and $64.2 million , $9.3 million , and $16.1 million , respectively, at December 31, 2015. At Cleco Power, the institutional money market funds were reported on Cleco Power’s Consolidated Balance Sheets in cash and cash equivalents, current restricted cash and cash equivalents, and non-current restricted cash and cash equivalents of $18.7 million , $23.1 million , and $23.3 million , respectively, at December 31, 2016 , and $62.0 million , $9.3 million , and $16.1 million , respectively, at December 31, 2015. If the money market funds failed to perform under the terms of the investments, Cleco and Cleco Power would be exposed to a loss of the invested amounts. Collateral on these types of investments is not required by either Cleco or Cleco Power. The Level 2 institutional money market funds asset consists of a single class. In order to capture interest income and minimize risk, cash is invested in money market funds that invest primarily in short-term securities issued by the U. S. Treasury to maintain liquidity and achieve the goal of a net asset value of a dollar. The risks associated with this class are counterparty risk of the fund manager and risk of price volatility associated with the underlying securities of the fund. Cleco Power’s FTRs were priced using MISO’s monthly auction prices. Forward seasonal periods are not included in every monthly auction; therefore, the average of the most recent seasonal auction prices is used for monthly valuation. FTRs are categorized as Level 3 fair value measurements because the only relevant pricing available comes from MISO auctions, which occur monthly in the Multi-Period Monthly Auction. The Level 2 long-term debt liability consists of a single class. In order to fund capital requirements, Cleco issues fixed and variable rate long-term debt with various tenors. The fair value of this class fluctuates as the market interest rates for fixed and variable rate debt with similar tenors and credit ratings change. The fair value of the debt could also change from period to period due to changes in the credit rating of the Cleco entity by which the debt was issued. During the years ended December 31, 2016 , and 2015 , Cleco did no t experience any transfers between levels within the fair value hierarchy. Commodity Contracts The following table presents the fair values of derivative instruments and their respective line items as recorded on Cleco and Cleco Power’s Consolidated Balance Sheets at December 31, 2016 , and 2015 : Cleco DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS SUCCESSOR PREDECESSOR (THOUSANDS) BALANCE SHEET LINE ITEM AT DEC. 31, 2016 AT DEC. 31, 2015 Commodity-related contracts FTRs: Current Energy risk management assets $ 7,884 $ 7,673 Current Energy risk management liabilities 201 275 Commodity-related contracts, net $ 7,683 $ 7,398 Cleco Power DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS (THOUSANDS) BALANCE SHEET LINE ITEM AT DEC. 31, 2016 AT DEC. 31, 2015 Commodity-related contracts FTRs: Current Energy risk management assets $ 7,884 $ 7,673 Current Energy risk management liabilities 201 275 Commodity-related contracts, net $ 7,683 $ 7,398 The following table presents the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Consolidated Statements of Income for the years December 31, 2016 , 2015 , and 2014 : Cleco AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES SUCCESSOR PREDECESSOR (THOUSANDS) DERIVATIVES LINE ITEM APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE Commodity contracts FTRs (1) Electric operations $ 30,915 $ 8,563 50,594 $ 74,454 FTRs (1) Power purchased for utility customers (14,941 ) (5,761 ) (27,509 ) (46,386 ) Total $ 15,974 $ 2,802 $ 23,085 $ 28,068 (1) For the periods January 1, 2016 - April 12, 2016, and April 13, 2016 - December 31, 2016, unrealized (losses) gains associated with FTRs of $(1.0) million and $3.1 million , respectively, were reported through Accumulated deferred fuel on the balance sheet. For the years ended December 31, 2015, and 2014, unrealized losses associated with FTRs of $1.5 million and $2.7 million , respectively, were reported through Accumulated deferred fuel on the balance sheet. Cleco Power AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES FOR THE YEAR ENDED DEC. 31, (THOUSANDS) DERIVATIVES LINE ITEM 2016 2015 2014 Commodity contracts FTRs (1) Electric operations $ 39,478 $ 50,594 $ 74,454 FTRs (1) Power purchased for utility customers (20,702 ) (27,509 ) (46,386 ) Total $ 18,776 $ 23,085 $ 28,068 (1) For the years ended December 31, 2016, 2015, and 2014, unrealized gains (losses) associated with FTRs of $2.1 million , $(1.5) million , and $(2.7) million , respectively, were reported through Accumulated deferred fuel on the balance sheet. At December 31, 2016 , and 2015 , 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 in the second half of 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. They are not designated as hedging instruments for accounting purposes. The total volume of FTRs that Cleco Power had outstanding at December 31, 2016 , and 2015 was 9.0 million MWh and 8.4 million MWh, respectively.

Debt

Debt	12 Months Ended
	Dec. 31, 2016
Debt Disclosure [Abstract]
Debt	Note 7 — Debt Cleco Power’s total indebtedness as of December 31, 2016 , and 2015 was as follows: Cleco Power AT DEC. 31, (THOUSANDS) 2016 2015 Bonds Senior notes, 6.65%, due 2018 $ — $ 250,000 Senior notes, 3.68%, due 2025 75,000 75,000 Senior notes, 3.47%, due 2026 130,000 — Senior notes, 4.33%, due 2027 50,000 50,000 Senior notes, 3.57%, due 2028 200,000 — Senior notes, 6.50%, due 2035 295,000 295,000 Senior notes, 6.00%, due 2040 250,000 250,000 Senior notes, 5.12%, due 2041 100,000 100,000 Series A GO Zone bonds, 2.00%, due 2038, mandatory tender in 2020 50,000 50,000 Series B GO Zone bonds, 4.25%, due 2038 50,000 50,000 Solid waste disposal facility bonds, 4.70%, due 2036, callable November 1, 2016 — 60,000 Cleco Katrina/Rita’s storm recovery bonds, 4.41%, due 2020 1,115 17,929 Cleco Katrina/Rita’s storm recovery bonds, 5.61%, due 2023 67,600 67,600 Total bonds 1,268,715 1,265,529 Other long-term debt Barge lease obligations, ending 2017 1,819 4,425 Gross amount of long-term debt 1,270,534 1,269,954 Less: long-term debt due within one year 17,896 16,814 Less: lease obligations classified as long-term debt due within one year 1,819 2,607 Unamortized debt discount (6,342 ) (6,885 ) Unamortized debt issuance costs (9,421 ) (9,609 ) Total long-term debt, net $ 1,235,056 $ 1,234,039 Cleco’s total indebtedness as of December 31, 2016 , and 2015 was as follows: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Total Cleco Power long-term debt, net $ 1,235,056 $ 1,234,039 Senior notes, 3.250%, due 2023 165,000 — Senior notes, 3.743%, due 2026 535,000 — Senior notes, 4.973%, due 2046 350,000 — Bank term loan, variable rate, due 2021 300,000 — Credit facility draws — 34,000 Unamortized debt issuance costs (2,261 ) (336 ) Fair value adjustment 155,776 — Total long-term debt, net $ 2,738,571 $ 1,267,703 The principal amounts payable under long-term debt agreements for each year through 2021 and thereafter are as follows: (THOUSANDS) CLECO CLECO POWER Amounts payable under long-term debt arrangements For the year ending Dec. 31, 2017 $ 17,896 $ 17,896 2018 $ 19,193 $ 19,193 2019 $ 20,571 $ 20,571 2020 $ 11,055 $ 11,055 2021 $ 300,000 $ — Thereafter $ 2,250,000 $ 1,200,000 At December 31, 2016 , Cleco and Cleco Power had $1.8 million of principal amounts payable in 2017 for a capital lease agreement for barges. For more information about the barge lease, see Note 15— “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Other Commitments — Fuel Transportation Agreement.” Cleco Power Debt Cleco Power had no short-term debt outstanding at December 31, 2016 , and 2015 . At December 31, 2016 , 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 December 31, 2016 , represents $17.9 million of principal payments for the Cleco Katrina/Rita storm recovery bonds and $ 1.8 million of capital lease payments. On November 1, 2016, Cleco Power redeemed at par $60.0 million of 4.70% Solid Waste Disposal Facility bonds due November 2036. As part of the redemption, Cleco Power paid $1.4 million of accrued interest on the redeemed bonds. On December 20, 2016, Cleco Power completed the private sale of $130.0 million of 3.47% senior notes due December 16, 2026, and $200.0 million of 3.57% senior notes due December 16, 2028. The proceeds from the issuance and sale of these notes were used to replace cash used to redeem the above mentioned Solid Waste Disposal Facility bonds, to redeem $250.0 million of 6.65% senior notes due 2018 prior to maturity and pay make-whole payments of approximately $19.0 million in connection with such redemption, and for general company purposes. Cleco Debt Cleco had no short-term debt outstanding at December 31, 2016 , and 2015 . At December 31, 2016 , Cleco’s long-term debt outstanding was $2.76 billion , of which $19.7 million was due within one year. The long-term debt due within one year at December 31, 2016 , represents $17.9 million of principal payments for the Cleco Katrina/Rita storm recovery bonds and $1.8 million of capital lease payments. In connection with the completion of the Merger, on April 13, 2016, Cleco Holdings entered into a $1.35 billion Acquisition Loan Facility. The Acquisition Loan Facility had a three -year term and a rate of LIBOR plus 1.75% or ABR plus 0.75% . In May and June 2016, Cleco Holdings refinanced the Acquisition Loan Facility with a series of other long-term financings described below. On May 17, 2016, Cleco Holdings completed the private sale of $535.0 million of 3.743% senior notes due May 1, 2026, and $350.0 million of 4.973% senior notes due May 1, 2046. On May 24, 2016, Cleco Holdings completed the private sale of $165.0 million of 3.250% senior notes due May 1, 2023. On June 28, 2016, Cleco Holdings entered into a $300.0 million variable rate bank term loan due June 28, 2021. Amounts outstanding under the bank term loan bear interest, at Cleco’s option, at a base rate plus 0.625% or LIBOR plus 1.625% . At December 31, 2016 , the all-in rate was 2.265% , which was based on the LIBOR rate. The proceeds from the issuance and sale of these notes and term loan were used to repay the $1.35 billion Acquisition Loan Facility. Debt issuance costs of $17.7 million were expensed to merger costs in connection with the repayment of the Acquisition Loan Facility. Credit Facilities At December 31, 2016 , Cleco had two separate revolving credit facilities, one for Cleco Holdings and one for Cleco Power, with a maximum aggregate capacity of $400.0 million . At December 31, 2015 , Cleco Power had a $300.0 million credit facility. On April 13, 2016, in connection with the completion of the Merger, Cleco Power replaced its existing credit facility. The new credit facility has similar terms as the previous facility, including restricted financial covenants, and expires in 2021. At December 31, 2016 , Cleco Power had no borrowings outstanding under its $300.0 million credit facility. The borrowing costs under Cleco Power’s new credit facility are equal to LIBOR plus 1.125% or ABR plus 0.125% , plus commitment fees of 0.125% . Under covenants contained in Cleco Power’s credit facility, Cleco Power is required to maintain total indebtedness equal to or less than 65% of total capitalization. At December 31, 2016 , $853.4 million of Cleco Power’s member’s equity was unrestricted. If Cleco Power were to default under its credit facility or any other debt agreements, Cleco Holdings would be considered to be in default under its facility. At December 31, 2016 , Cleco Power was in compliance with the covenants in its credit facility. A $2.0 million letter of credit issued to MISO is covered under a standing letter of credit outside of Cleco Power’s credit facility; therefore, it does not reduce the borrowing capacity of Cleco Power’s new credit facility. At December 31, 2015 , Cleco Holdings had a $250.0 million credit facility. On April 13, 2016, in connection with the completion of the Merger, Cleco Holdings replaced the existing credit facility with a $100.0 million credit facility. The new credit facility has similar terms as the previous facility, including restricted financial covenants, and expires in 2021. At December 31, 2016 , Cleco Holdings had no borrowings outstanding under its $100.0 million credit facility. The borrowing costs under Cleco Holdings’ new credit facility are equal to LIBOR plus 1.75% or ABR plus 0.75% , plus commitment fees of 0.275% . Under covenants contained in Cleco Holdings’ credit facility, Cleco is required to maintain total indebtedness equal to or less than 65% of total capitalization. At December 31, 2016 , $634.6 million of Cleco’s member’s equity was unrestricted. At December 31, 2016 , Cleco Holdings was in compliance with the covenants of its credit facility.

Common Stock

Common Stock	12 Months Ended
	Dec. 31, 2016
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Common Stock	Note 8 — Common Stock Stock-Based Plan Descriptions and Share Information 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. For more information about the Merger, see Note 3 — “Business Combinations.” Employee Stock Purchase Plan Prior to October 17, 2014, regular, full-time, and part-time employees of Cleco Corporation and its participating subsidiaries, except officers, general managers, and employees who owned 5% or more of Cleco Corporation’s stock, were eligible to participate in the ESPP. No trust or other fiduciary account was established in connection with the ESPP. Shares of common stock were purchased at a 5% discount of the fair market value as of the last trading day of each calendar quarter. A participant could purchase a maximum of 125 shares per offering period. Dividends received on shares were automatically reinvested as required by the dividend reinvestment plan (DRIP) provisions of the ESPP. A maximum of 73,400 shares of common stock was available to be purchased under the ESPP, subject to adjustment for changes in the capitalization of Cleco Corporation. The Compensation Committee of Cleco Corporation’s Board of Directors monitored the ESPP. The Compensation Committee and the Board of Directors possessed the authority to amend the ESPP, but shareholder approval was required for any amendment that increased the number of shares covered by the ESPP. As stated above, the ESPP plan was terminated upon completion of the Merger. Long-Term Incentive Compensation Plan Prior to the completion of the Merger, stock options, restricted stock, also known as non-vested stock, common stock equivalent units, and stock appreciation rights were available to be granted or awarded to certain officers, key employees, or directors of Cleco Corporation and its affiliates under the LTIP. On December 31, 2009, the 2000 LTIP expired and no further grants or awards were made under this plan. During 2015, all restrictions on non-vested shares previously awarded pursuant to the 2000 LTIP had lapsed. With shareholder approval, the 2010 LTIP became effective January 1, 2010. Under this plan, a maximum of 2,250,000 shares of Cleco Corporation’s common stock was available to be granted or awarded. During 2015, Cleco granted 9,611 shares of stock to directors of Cleco pursuant to the LTIP. All of these shares vested immediately upon award and were issued from shares previously purchased through Cleco’s common stock repurchase program. As stated above, the LTIP plan was terminated upon completion of the Merger. Non-Vested Stock and Common Stock Equivalent Units Prior to the completion of the Merger, Cleco granted non-vested stock to certain officers, key employees, and directors. Because it was only to be settled in shares of Cleco Corporation common stock, non-vested stock was classified as equity. Recipients of non-vested stock had full voting rights of a stockholder. At the time restrictions lapsed, the accrued dividend equivalent units were paid to the recipient only to the extent that target shares vested. In order to vest, the non-vested stock required the satisfaction of a service requirement and a market-based requirement. Recipients of non-vested stock were eligible to receive opportunity instruments if certain market-based measures were exceeded. Cleco also awarded non-vested stock with only a service period requirement to certain employees and directors. These awards required the satisfaction of a predetermined service period in order for the shares to vest. During the predecessor period January 1, 2016, through April 12, 2016 , Cleco granted no shares of non-vested stock pursuant to the LTIP. As a result of the Merger on April 13, 2016, all unvested shares outstanding under the LTIP that were granted prior to January 1, 2015, vested at target and were paid out in cash to plan participants. Unvested shares that were granted during 2015 were prorated to the target amount and paid out in cash to plan participants in accordance with the terms of the Merger Agreement. A summary of non-vested stock activity during 2016 is presented in the following table: PREDECESSOR SHARES WEIGHTED-AVERAGE GRANT-DATE FAIR VALUE Non-vested at Jan. 1, 2016 269,988 $ 48.11 Vested (217,588 ) $ 46.53 Forfeited (52,400 ) $ 54.64 Non-vested at Apr. 12, 2016 — $ — The fair value of shares of non-vested stock that vested during the predecessor period January 1, 2016, through April 12, 2016, was $10.1 million . The fair value of shares of non-vested stock that vested during the predecessor years ended December 31, 2015, and 2014 was $3.3 million and $5.6 million , respectively. The fair value of shares of non-vested stock granted during 2015 and 2014 under the LTIP was estimated on the date of grant and the expense was calculated using the Monte Carlo simulation model with the assumptions listed in the following table: PREDECESSOR FOR THE YEAR ENDED DEC. 31, 2015 FOR THE YEAR ENDED DEC. 31, 2014 Expected term (in years) (1) 3.0 3.0 Volatility of Cleco stock (2) 15.8 % 17.3 % Correlation between Cleco stock volatility and peer group 63.1 % 66.5 % Expected dividend yield 2.9 % 3.0 % Weighted average fair value (Monte Carlo model) $ 45.60 $ 54.58 (1) The expected term was based on the service period of the award. (2) The volatility rate is based on historical stock prices over an appropriate period, generally equal to the expected term. Stock-Based Compensation During 2016 , 2015 , and 2014 , Cleco did not modify any of the terms of outstanding awards. Cleco recognized stock-based compensation expense for these provisions in accordance with the non-substantive vesting period approach. Prior to the completion of the Merger, Cleco recorded compensation expense for all non-vested stock. Assuming achievement of vesting requirements was probable, stock-based compensation expense of non-vested stock was recorded during the service periods, which were generally three years. All stock-based compensation cost was measured at the grant date based on the fair value of the award and was recognized as an expense in the income statement over the requisite service period of the award. Awards that vest pro rata during the requisite service period that contain only a service condition were defined as having a graded vesting schedule and could have been treated as multiple awards with separate vesting schedules. However, Cleco elected to treat grants with graded vesting schedules as one award and recognized the related compensation expense on a straight-line basis over the requisite service period. In April 2016, Cleco incurred $2.3 million of merger expense due to accelerated vesting of the LTIP shares. The ESPP did not contain optionality features beyond those listed by the authoritative guidance on stock-based compensation. Therefore, Cleco was not required to recognize a fair-value expense related to the ESPP. Cleco and Cleco Power reported pretax compensation expense for their share-based compensation plans as shown in the following tables: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE YEAR ENDED DEC. 31, 2015 FOR THE Equity classification Non-vested stock (1) $ — $ 3,241 $ 6,110 $ 6,308 Tax benefit $ — $ 1,247 $ 2,351 $ 2,427 (1) For each of the years ended December 31, 2015 , and 2014 , compensation expense included in Cleco’s Consolidated Statements of Income related to non-forfeitable dividends paid on non-vested stock that was not expected to vest was $0.1 million . For the predecessor period January 1, 2016, through April 12, 2016, compensation expense included in Cleco’s Consolidated Statements of Income related to non-forfeitable dividends paid on non-vested stock that was not expected to vest was less than $0.1 million . Cleco Power FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Equity classification Non-vested stock $ 997 $ 2,000 $ 2,004 Tax benefit $ 384 $ 770 $ 771 The amount of stock-based compensation capitalized in property, plant, and equipment on Cleco’s Consolidated Balance Sheets for the predecessor periods January 1, 2016, through April 12, 2016 , and January 1, 2015, through December 31, 2015 , was $0.6 million and $0.8 million , respectively. The amount of stock-based compensation capitalized in property, plant, and equipment on Cleco Power’s Consolidated Balance Sheets for the years ended December 31, 2016 , and 2015 was $0.6 million and $0.7 million , respectively. Common Stock Repurchase Program Prior to the completion of the Merger, Cleco Corporation had a common stock repurchase program that authorized management to repurchase shares of common stock. During the predecessor periods January 1, 2016, through April 12, 2016 , and January 1, 2015, through December 31, 2015 , no shares of common stock were repurchased. During the predecessor year ended December 31, 2014 , 250,000 shares of common stock were repurchased. Upon completion of the Merger on April 13, 2016, the common stock repurchase program was terminated. For more information about the Merger, see Note 3 — “Business Combinations.”

Pension Plan and Employee Benef

Pension Plan and Employee Benefits	12 Months Ended
	Dec. 31, 2016
Compensation and Retirement Disclosure [Abstract]
Pension Plan and Employee Benefits	Note 9 — 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 2015, nor does it 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 employee pension plan and other benefits obligation plan assets and funded status at December 31, 2016 , and 2015 are presented in the following table: PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE APR. 13, 2016 - JAN. 1, 2016 - FOR THE Change in benefit obligation Benefit obligation at beginning of period $ 499,724 $ 480,062 $ 498,372 $ 42,707 $ 43,070 $ 44,652 Service cost 6,909 2,563 10,419 1,112 431 1,635 Interest cost 15,088 6,242 20,795 1,237 476 1,607 Plan participants’ contributions — — — 758 300 903 Actuarial loss (gain) 6,242 16,857 (30,483 ) 2,292 — (1,039 ) Expenses paid (2,025 ) (801 ) (1,995 ) — — — Medicare D — — — — — 48 Benefits paid (13,153 ) (5,199 ) (17,046 ) (3,970 ) (1,570 ) (4,736 ) Benefit obligation at end of period 512,785 499,724 480,062 44,136 42,707 43,070 Change in plan assets Fair value of plan assets at beginning of period 398,515 383,532 412,803 — — — Actual return on plan assets 20,378 20,983 (10,230 ) — — — Expenses paid (2,025 ) (801 ) (1,995 ) — — — Benefits paid (13,153 ) (5,199 ) (17,046 ) — — — Fair value of plan assets at end of period 403,715 398,515 383,532 — — — Unfunded status $ (109,070 ) $ (101,209 ) $ (96,530 ) $ (44,136 ) $ (42,707 ) $ (43,070 ) The employee pension plan accumulated benefit obligation at December 31, 2016 , and 2015 is presented in the following table: PENSION BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Accumulated benefit obligation $ 473,197 $ 440,876 The following table presents the net actuarial gains/losses, transition obligations/assets, and prior service costs included in other comprehensive income for other benefits and in regulatory assets for pension related to current year gains and losses as a result of being included in net periodic benefit costs for the employee pension plan and other benefits plan at December 31, 2016 , and 2015 : PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE APR. 13, 2016 - JAN. 1, 2016 - FOR THE Net actuarial (gain) loss occurring during period $ (10,198 ) $ 16,056 $ 3,128 $ 2,292 $ — $ (1,039 ) Net actuarial loss amortized during period $ 8,138 $ 2,798 $ 13,828 $ — $ 181 $ 866 Prior service (credit) cost amortized during period $ (51 ) $ (20 ) $ (71 ) $ — $ 34 $ 119 The following table presents net gains/losses and prior period service costs/credits in accumulated other comprehensive income for other benefits and in regulatory assets for pension that have not been recognized as components of net periodic benefit costs and the amounts expected to be recognized in 2017 for the employee pension plan and other benefits plans for December 31, 2017 , 2016 , and 2015 : PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2017 AT DEC. 31, 2016 AT DEC. 31, 2015 AT DEC. 31, 2017 AT DEC. 31, 2016 AT DEC. 31, 2015 Net actuarial loss $ 9,647 $ 145,542 $ 150,620 $ — $ 2,292 $ 8,805 Prior service (credit) cost $ (71 ) $ (274 ) $ (345 ) $ — $ — $ 363 The components of net periodic pension and other benefits costs for 2016 , 2015 , and 2014 are as follows: PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE Components of periodic benefit costs Service cost $ 6,909 $ 2,563 $ 10,419 $ 8,050 $ 1,112 $ 431 $ 1,635 $ 1,542 Interest cost 15,088 6,242 20,795 19,851 1,237 476 1,607 1,809 Expected return on plan assets (17,310 ) (6,812 ) (23,382 ) (24,507 ) — — — — Amortizations Transition obligation — — — — — — — 16 Prior period service (credit) cost (51 ) (20 ) (71 ) (71 ) — 34 119 119 Net loss 8,138 2,798 13,828 6,743 — 181 866 670 Net periodic benefit cost $ 12,774 $ 4,771 $ 21,589 $ 10,066 $ 2,349 $ 1,122 $ 4,227 $ 4,156 During the third quarter of 2016, management finalized its remeasurement of the pension plan as of April 13, 2016, associated with the Merger. On the date of the remeasurement, the discount rate decreased from 4.62% to 4.21% . Prior to the remeasurement, Cleco’s 2016 net periodic benefit cost for the pension plan was expected to be $15.9 million . Due to the remeasurement of the pension plan, Cleco’s 2016 net periodic benefit cost increased to $17.5 million . 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 predecessor period January 1, 2016, through April 12, 2016, was $0.5 million . The expense of the pension plan related to Cleco’s other subsidiaries for the successor period April 13, 2016, through December 31, 2016 was $1.3 million . The amounts for the predecessor periods for 2015 , and 2014 were $2.1 million and $1.7 million , respectively. Cleco Holdings is the plan sponsor for the other benefit plans. There are no assets set aside in a trust and the liabilities are reported on the individual subsidiaries’ financial statements. The expense related to other benefits reflected in Cleco Power’s Consolidated Statements of Income for the years ended December 31, 2016 , 2015 , and 2014 was $3.5 million , $3.6 million , and $3.6 million , respectively. The current and non-current portions of the other benefits liability for Cleco and Cleco Power at December 31, 2016 , and 2015 are as follows: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current $ 3,854 $ 3,613 Non-current $ 40,196 $ 39,457 Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current $ 3,345 $ 3,140 Non-current $ 34,892 $ 34,300 In March 2010, the President signed the PPACA, a comprehensive health care law. While all provisions of the PPACA are not effective immediately and the law has been amended since original enactment, management does not expect the provisions to materially impact Cleco’s retiree medical unfunded liability and related expenses. Management will continue to monitor this law and its possible impact. The measurement date used to determine the pension and other postretirement benefits is December 31. The assumptions used to determine the benefit obligation and the periodic costs are as follows: PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR AT DEC. 31, 2016 AT DEC. 31, 2015 AT DEC. 31, 2016 AT DEC. 31, 2015 Weighted-average assumptions used to determine the benefit obligation Discount rate 4.27 % 4.62 % 3.81 % 4.08 % Rate of compensation increase 3.03 % 3.08 % N/A N/A PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE Weighted-average assumptions used to determine the net benefit cost Discount rate 4.21 % 4.62 % 4.21 % 5.14 % 4.08 % 4.08 % 3.76 % 4.46 % Expected return on plan assets 6.21 % 6.21 % 6.15 % 6.76 % N/A N/A N/A N/A Rate of compensation increase 3.03 % 3.03 % 3.08 % 3.17 % N/A N/A N/A N/A The expected return on plan assets was determined by examining the risk profile of each target category as compared to the expected return on that risk, within the parameters determined by the retirement committee. The result was also compared to the expected rate of return of other comparable plans. In assessing the risk as compared to return profile, historical returns as compared to risk were considered. The historical risk compared to returns was adjusted for the expected future long-term relationship between risk and return. The adjustment for the future risk compared to returns was, in part, subjective and not based on any measurable or observable events. For the calculation of the 2017 periodic expense, Cleco decreased the expected long-term return on plan assets to 6.08% . Cleco expects pension expense to decrease in 2017 by approximately $2.2 million due to a higher than expected return on assets in 2016 and favorable mortality improvement scale updates, partially offset by a decrease in the discount rate. Employee pension plan assets may be invested in publicly traded domestic common stocks; U.S. Government, federal agency, and corporate obligations; an international equity fund, commercial real estate funds; and pooled temporary investments. Investments in securities (obligations of U.S. Government, U.S. Government Agencies, and state and local governments, corporate debt, common/collective trust funds, mutual funds, common stocks, and preferred stock) traded on a national securities exchange are valued at the last reported sales price on the last business day of the year. Real estate funds and the pooled separate accounts are stated at estimated market value based on appraisal reports prepared annually by independent real estate appraisers (members of the American Institute of Real Estate Appraisers). The estimated market value of recently acquired properties is assumed to approximate cost. Fair Value Disclosures Cleco classifies assets and liabilities measured at their fair value according to three different levels, depending on the inputs used in determining fair value. • Level 1 – unadjusted quoted prices in active, liquid markets for the identical asset or liability, • Level 2 – quoted prices for similar assets and liabilities in active markets or other inputs that are observable for the asset or liability, including inputs that can be corroborated by observable market data, observable interest rate yield curves and volatilities, and • Level 3 – unobservable inputs based upon the entities’ own assumptions. There have been no changes in the methodologies for determining fair value at December 31, 2016 , and December 31, 2015 . The following tables disclose the pension plan’s fair value of financial assets measured on a recurring basis: SUCCESSOR (THOUSANDS) 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 Cash equivalents $ 6,817 $ — $ 6,817 $ — Common stock 19,311 19,311 — — Obligations of U.S. Government, U.S. Government Agencies, and state and local governments 47,543 — 47,543 — Mutual funds Domestic 52,663 52,663 — — International 31,191 31,191 — — Real estate funds 18,668 — — 18,668 Corporate debt 185,659 — 185,659 — Total $ 361,852 $ 103,165 $ 240,019 $ 18,668 Investments measured at net asset value* 38,886 Interest accrual 2,977 Total net assets $ 403,715 *Investments measured at net asset value consist of Common/collective trust. PREDECESSOR (THOUSANDS) AT DEC. 31, 2015 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) Asset Description Cash equivalents $ 4,568 $ — $ 4,568 $ — Common stock 13,816 13,816 — — Obligations of U.S. Government, U.S. Government Agencies, and state and local governments 48,792 — 48,792 — Mutual funds Domestic 47,801 47,801 — — International 22,853 22,853 — — Real estate funds 17,890 — — 17,890 Corporate debt 182,408 — 182,408 — Total $ 338,128 $ 84,470 $ 235,768 $ 17,890 Investments measured at net asset value* 42,362 Interest accrual 3,042 Total net assets $ 383,532 *Investments measured at net asset value consist of Hedge fund-of-funds and Common/collective trust. Level 3 valuations are derived from other valuation methodologies including pricing models, discounted cash flow models, and similar techniques. Level 3 valuations incorporate subjective judgments and consider assumptions including capitalization rates, discount rates, cash flows, and other factors that are not observable in the market. Significant increases or decreases in any of those inputs in isolation would result in a significantly different fair value measurement. The following is a reconciliation of the beginning and ending balances of the pension plan’s real estate funds measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the years ended December 31, 2016 , and 2015 : (THOUSANDS) PREDECESSOR Balance, Dec. 31, 2014 $ 18,792 Realized gains 9 Unrealized losses (148 ) Purchases 679 Sales (1,442 ) Balance, Dec. 31, 2015 $ 17,890 Realized gains 71 Unrealized gains 89 Purchases 26 Sales (205 ) Balance, Apr. 12, 2016 $ 17,871 SUCCESSOR Balance, Apr. 13, 2016 $ 17,871 Realized gains 151 Unrealized gains 226 Purchases 570 Sales (151 ) Balance, Dec. 31, 2016 $ 18,668 The market-related value of plan assets differs from the fair value of plan assets by the amount of deferred asset gains or losses. Actual asset returns that differ from the expected return on plan assets are deferred and recognized in the market-related value of assets on a straight-line basis over a five-year period. For 2016 , the return on plan assets was 10.90% compared to an expected long-term return of 6.21% . The 2015 return on pension plan assets was (2.90)% compared to an expected long-term return of 6.15% . As of December 31, 2016 , none of the pension plan participants’ future annual benefits are covered by insurance contracts. In December 2008, Cleco became aware that, through its hedge fund-of-funds manager, a portion of its pension plan assets were invested in the Madoff feeder fund investment, Ascot Fund Limited. In January 2009, Cleco Power elected to liquidate the holdings of the hedge fund-of-funds manager. At December 31, 2016 , all investments in the hedge fund-of-funds had been liquidated. Proceeds from the hedge fund-of-funds manager were reallocated to the plan’s other investment managers. The hedge fund-of-funds investment was measured at fair value using the net asset value per share as a practical expedient (or its equivalent) and was not classified in the fair value hierarchy for 2016. Pension Plan Investment Objectives Cleco’s retirement committee has established investment performance objectives of the pension plan assets. Over a three- to five-year period, the objectives are for the pension plan’s annualized total return to: • Exceed the assumed rate of return on plan assets, and • Exceed the annualized total return of a customized index consisting of a mixture of S&P 500 Index, Russell 2500 Index, MSCI EAFE Index, Morgan Stanley Capital International Emerging Markets Index, Barclays Capital Long Credit Index, Barclays Capital Long Government/Credit Index, National Council of Real Estate Investment Fiduciaries Index, and U.S. Treasury Bills plus 5%. In order to meet the objectives and to control risk, the retirement committee has established the following guidelines that the investment managers must follow: Domestic Equity Portfolios • Equity holdings of a single company must not exceed 10% of the manager’s portfolio. • A minimum of 25 stocks should be owned. • Equity holdings in a single sector should not exceed the lesser of three times the sector’s weighting in the S&P 500 Index or 35% of the portfolio. • Equity holdings should represent at least 90% of the portfolio. • Marketable common stocks, preferred stocks convertible into common stocks, and fixed income securities convertible into common stocks are the only permissible equity investments. • Securities in foreign entities denominated in U.S. dollars are limited to 10%. Securities denominated in currencies other than U.S. dollars are not permitted. • The purchase of securities on margin and short sales is prohibited. International Equity Portfolios Developed Markets • Equity holdings of a single company should not exceed 5% of the manager’s portfolio. • A minimum of 30 stocks should be owned. • Equity holdings in a single sector should not exceed 35%. • A minimum of 50% of the countries within the MSCI EAFE Index should be represented within the portfolio. The allocation to an individual country should not exceed the lesser of 30% or 5 times the country’s weighting within the MSCI EAFE Index. • Currency hedging decisions are at the discretion of the investment manager. Emerging Markets • Equity holdings in any single company should not exceed 10% of the manager’s portfolio. • A minimum of 30 individual stocks should be owned. • Equity holdings of a single industry should not exceed 25%. • Equity investments must represent at least 75% of the manager’s portfolio. • A minimum of three countries should be represented within the manager’s portfolio. • Illiquid securities which are not readily marketable may represent no more than 10% of the manager’s portfolio. • Currency hedging decisions are at the discretion of the investment manager. Fixed Income Portfolio - Long Government/Credit • Only U.S. dollar denominated assets permitted, including U.S. government and agency securities, corporate securities, structured securities, other interest-bearing securities, and short-term investments. • At least 85% of the debt securities should be investment grade securities (BBB- by S&P or Baa3 by Moody’s) or higher. • Debt holdings of a single issue or issuer must not exceed 5% of the manager’s portfolio. • Aggregate net notional exposure of futures, options, and swaps must not exceed 30% of the manager’s portfolio. Manager will only execute swaps with counterparties whose credit rating is A2/A or better. • Margin purchases or leverage is prohibited. • The average weighted duration of portfolio security holdings, including derivative exposure, is expected to range within +/- 20% of the Barclays Long Gov/Credit Index duration. Fixed Income Portfolio - Long Credit • Permitted assets include U.S. government and agency securities, corporate securities, mortgage-backed securities, investment-grade private placements, surplus notes, trust preferred, e-caps and hybrids, money-market securities, and senior and subordinated debt. • At least 90% of securities must be U.S. dollar denominated. • At least 70% of the securities must be investment-grade credit. • Securities must have a maximum position size of 5% for A rated securities and 3% for BBB rated securities. • The duration of the portfolio must be within +/- 1 year of benchmark. Real Estate Portfolios • Real estate funds should be invested primarily in direct equity positions, with debt and other investments representing less than 25% of the fund. • Leverage should be no more than 70% of the market value of the fund. • Investments should be focused on existing income-producing properties, with land and development properties representing less than 40% of the fund. The use of futures and options positions which leverage portfolio positions through borrowing, short sales, or other encumbrances of the Plan’s assets is prohibited: • Debt portfolios are exempt from the prohibition on derivative use. • Execution of target allocation rebalancing may be implemented through short- to intermediate-term use of derivatives overlay strategies. The notional value of derivative positions shall not exceed 20% of the total pension fund’s value at any given time. The following chart shows the dynamic asset allocation based on the funded ratio at December 31, 2016 : PERCENT OF TOTAL PLAN ASSETS MINIMUM TARGET MAXIMUM Return-seeking Domestic equity 18 % International equity 17 % Real estate 5 % Total return-seeking 35 % 40 % 45 % Liability hedging* 55 % 60 % 65 % *Liability hedging is not target by subcategories. The assumed health care cost trend rates used to measure the expected cost of other benefits is 5.0% for 2017 and remains at 5.0% thereafter. The rate used for 2016 was also 5.0% . Assumed health care cost trend rates have a limited effect on the amount reported for Cleco’s health care plans. A one-percentage point change in assumed health care cost trend rates would have the following effects on other benefits: ONE-PERCENTAGE POINT (THOUSANDS) INCREASE DECREASE Effect on total of service and interest cost components $ 19 $ (22 ) Effect on postretirement benefit obligation $ 238 $ (265 ) The projected benefit payments for the employee pension plan and other benefits obligation plan for each year through 2021 and the next five years thereafter are listed in the following table: (THOUSANDS) PENSION BENEFITS OTHER BENEFITS, GROSS 2017 $ 20,152 $ 3,927 2018 $ 21,265 $ 3,951 2019 $ 22,382 $ 4,002 2020 $ 23,719 $ 4,006 2021 $ 24,818 $ 3,993 Next five years $ 141,584 $ 18,190 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 will have their annual bonuses set at target rather than actual awards for years 2016 and 2017 for the average incentive award portion of their SERP benefit calculation. 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. 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 from which the officer retired. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator. SERP’s funded status at December 31, 2016 , and 2015 is presented in the following table: SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - APR. 12, 2016 FOR THE Change in benefit obligation Benefit obligation at beginning of period $ 79,555 $ 72,315 $ 73,902 Service cost 571 702 2,705 Interest cost 2,275 900 3,056 Actuarial loss (gain) 1,152 — (4,488 ) Benefits paid (2,999 ) (1,186 ) (2,860 ) Plan amendments (2,509 ) Curtailments 3,602 Special/contractual termination benefits 3,222 Benefit obligation at end of period $ 78,045 $ 79,555 $ 72,315 SERP’s accumulated benefit obligation at December 31, 2016 , and 2015 is presented in the following table: SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Accumulated benefit obligation $ 76,194 $ 65,840 The following table presents net actuarial gains/losses and prior service costs included in other comprehensive income or regulatory assets related to current year gains and losses as a result of being amortized as a component of net periodic benefit costs for SERP at December 31, 2016 , and 2015 : SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - APR. 12, 2016 FOR THE Net actuarial gain occurring during year $ (1,345 ) $ — $ (4,487 ) Net actuarial loss amortized during year $ 1,651 $ 574 $ 2,973 Prior service (credit) cost amortized during year $ (50 ) $ 17 $ 54 The following table presents net gains/losses and prior period service costs/credit in accumulated other comprehensive income and regulatory assets that have not been recognized as components of net periodic benefit costs and the amounts expected to be recognized in 2017 for SERP for December 31, 2017 , 2016 , and 2015 : SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2017 AT DEC. 31, 2016 AT DEC. 31, 2015 Net actuarial loss $ 1,634 $ 20,999 $ 23,763 Prior service (credit) cost $ (190 ) $ (2,368 ) $ 120 The components of the net SERP costs for 2016 , 2015 , and 2014 are as follows: SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE Components of periodic benefit costs Service cost $ 571 $ 702 $ 2,705 $ 2,278 Interest cost 2,275 900 3,056 3,028 Amortizations Prior period service (credit) cost (50 ) 17 54 54 Net loss 1,651 574 2,973 1,875 Net periodic benefit cost $ 4,447 $ 2,193 $ 8,788 $ 7,235 Curtailment charge $ — $ 3,602 $ — $ — Special/contractual termination benefits $ — $ 3,222 $ — $ — Total benefit cost $ 4,447 $ 9,017 $ 8,788 $ 7,235 There was a remeasurement of SERP at April 13, 2016, to reflect change in control benefits as a result of the Merger. On the date of the remeasurement, the discount rate decreased from 4.60% to 4.15% . This remeasurement resulted in a $3.6 million curtailment charge and $3.2 million of special/contractual termination benefits. The curtailments and special/contractual termination benefits are included in Merger transaction and commitment costs on Cleco’s Consolidated Statements of Income. There was an additional remeasurement of SERP at August 31, 2016, to reflect changes to the plan relating to three executive officers’ SERP benefits being capped as of December 31, 2017, with regard to final compensation. On the date of the remeasurement, the discount rate decreased from 4.15% to 3.47% . The measurement date used to determine the SERP benefits is December 31. The assumptions used to determine the benefit obligation and the periodic costs are as follows: SERP SUCCESSOR PREDECESSOR AT DEC. 31, 2016 AT DEC. 31, 2015 Weighted-average assumptions used to determine the benefit obligation Discount rate 4.22 % 4.60 % Rate of compensation increase 5.00 % 5.00 % SERP SUCCESSOR PREDECESSOR SEPT. 1, 2016 - DEC. 31, 2016 APR. 13, 2016 - AUG. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE Weighted-average assumptions used to determine the net benefit cost Discount rate 3.47 % 4.15 % 4.60 % 4.20 % 5.09 % Rate of compensation increase 5.00 % 5.00 % 5.00 % 5.00 % 5.00 % The expense related to SERP reflected on Cleco Power’s Consolidated Statements of Income for the years ended December 31, 2016 , 2015 , and 2014 was $1.4 million , $2.2 million , and $1.7 million , respectively. Liabilities relating to SERP are reported on the individual subsidiaries’ financial statements.The current and non-current portions of the SERP liability for Cleco and Cleco Power at December 31, 2016 , and 2015 are as follows: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current $ 4,308 $ 3,238 Non-current $ 73,738 $ 69,049 Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current $ 885 $ 1,000 Non-current $ 15,145 $ 21,321 The projected benefit payments for the SERP for each year through 2021 and the next five years thereafter are shown in the following table: (THOUSANDS) 2017 2018 2019 2020 2021 NEXT FIVE YEARS SERP $ 4,399 $ 4,444 $ 4,483 $ 4,558 $ 4,578 $ 23,168 401(k) Cleco’s 401(k) Plan is intended to provide active, eligible employees with voluntary, long-term savings and investment opportunities. The 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 Plan, employer contributions can be in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Participation in the Plan is voluntary and active Cleco employees are eligible to participate. Cleco’s 401(k) Plan expense for the years ended December 31, 2016 , 2015 , and 2014 is as follows: SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE 401(k) Plan expense $ 3,554 $ 1,593 $ 5,029 $ 4,730 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 years ended December 31, 2016 , 2015 , and 2014 is as follows: SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE 401(k) Plan expense $ 554 $ 319 $ 944 $ 921

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Tax Disclosure [Abstract]
Income Taxes	Note 10 — Income Taxes Cleco For the successor period April 13, 2016, through December 31, 2016 , and the predecessor period for the year ended December 31, 2015, income tax expense was higher than the amount computed by applying the statutory federal rate. For the predecessor period January 1, 2016, through April 12, 2016, and for the predecessor period for the year ended December 31, 2014 , income tax expense was lower than the amount computed by applying the statutory federal rate. The differences are as follows: SUCCESSOR PREDECESSOR (THOUSANDS, EXCEPT FOR %) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE YEAR ENDED DEC. 31, 2015 FOR THE Income before tax $ (46,935 ) $ (492 ) $ 211,373 $ 221,855 Statutory rate 35.0 % 35.0 % 35.0 % 35.0 % Tax at federal statutory rate $ (16,427 ) $ (172 ) $ 73,981 $ 77,649 Increase (decrease) Plant differences, including AFUDC flowthrough (881 ) 823 1,875 462 Amortization of investment tax credits (371 ) (124 ) (916 ) (983 ) State income taxes (4,725 ) (3,078 ) 1,117 23 Nondeductible merger costs (844 ) 4,282 — — Settlement with taxing authorities — — — (9,106 ) Return to accrual adjustment (2,943 ) — — — NMTC (181 ) (158 ) 243 (754 ) Other 3,550 1,895 1,404 (175 ) Total tax (benefit) expense $ (22,822 ) $ 3,468 $ 77,704 $ 67,116 Effective Rate 48.6 % (704.9 )% 36.8 % 30.3 % Information about current and deferred income tax expense is as follows: SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE Current federal income tax (benefit) expense $ (1,062 ) $ 1,373 $ 1,284 $ 11,082 Deferred federal income tax (benefit) expense (16,715 ) 5,297 76,219 71,061 Amortization of accumulated deferred investment tax credits (371 ) (124 ) (916 ) (983 ) Total federal income tax (benefit) expense $ (18,148 ) $ 6,546 $ 76,587 $ 81,160 Current state income tax (benefit) expense (337 ) — 3,233 (6,580 ) Deferred state income tax (benefit) expense (4,337 ) (3,078 ) (2,116 ) (7,464 ) Total state income tax (benefit) expense $ (4,674 ) $ (3,078 ) $ 1,117 $ (14,044 ) Total federal and state income tax (benefit) expense $ (22,822 ) $ 3,468 $ 77,704 $ 67,116 Items charged or credited directly to member’s/shareholders’ equity Federal deferred 14,593 (277 ) 3,274 (3,656 ) State deferred 2,441 (45 ) 528 (590 ) Total tax expense (benefit) from items charged directly to member’s/shareholders’ equity $ 17,034 $ (322 ) $ 3,802 $ (4,246 ) Total federal and state income tax (benefit) expense $ (5,788 ) $ 3,146 $ 81,506 $ 62,870 The balance of accumulated deferred federal and state income tax assets and liabilities at December 31, 2016 , and 2015 was comprised of the following: SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Depreciation and property basis differences $ (943,552 ) $ (948,597 ) Net operating loss carryforward 54,727 12,092 NMTC 89,411 87,544 Fuel costs (8,802 ) (7,833 ) Other comprehensive income 3,399 15,774 Regulated operations regulatory liability, net (91,734 ) (90,122 ) Postretirement benefits other than pension 22,733 11,561 Merger fair value adjustments (124,254 ) — Other (34,983 ) (5,522 ) Accumulated deferred federal and state income taxes, net $ (1,033,055 ) $ (925,103 ) 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 December 31, 2016 , and 2015 , Cleco had a deferred tax asset resulting from NMTC carryforwards of $97.5 million and $96.5 million , respectively. 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 December 31, 2016 , Cleco had a federal net operating loss carryforward of $89.9 million and a state net operating loss carryforward of $201.1 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 payments of income taxes and Cleco expects to utilize the entire net operating loss carryforward within the statutory deadlines. Cleco Power For the years ended December 31, 2016, and 2014 income tax expense was lower than the amount computed by applying the statutory rate. For the year ended December 31, 2015, income tax expense was higher than the amount computed by applying the statutory federal rate to income before tax. The differences are as follows: FOR THE YEAR ENDED DEC. 31, (THOUSANDS, EXCEPT FOR %) 2016 2015 2014 Income before tax $ 57,497 $ 220,644 $ 231,290 Statutory rate 35.0 % 35.0 % 35.0 % Tax at federal statutory rate $ 20,124 $ 77,225 $ 80,952 Increase (decrease): Plant differences, including AFUDC flowthrough (58 ) 1,875 462 Amortization of investment tax credits (494 ) (916 ) (983 ) State income taxes (2,573 ) 1,501 351 Settlement with taxing authorities — — (2,320 ) Return to accrual adjustment (2,646 ) — — Other 4,016 (391 ) (1,488 ) Total taxes $ 18,369 $ 79,294 $ 76,974 Effective Rate 31.9 % 35.9 % 33.3 % Information about current and deferred income tax expense is as follows: FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Current federal income tax (benefit) expense $ (1,211 ) $ 33,138 $ (197 ) Deferred federal income tax expense 22,647 45,572 83,676 Amortization of accumulated deferred investment tax credits (494 ) (916 ) (983 ) Total federal income tax expense $ 20,942 $ 77,794 $ 82,496 Current state income tax (benefit) expense (418 ) 3,397 (4,161 ) Deferred state income tax benefit (2,155 ) (1,897 ) (1,361 ) Total state income tax (benefit) expense $ (2,573 ) $ 1,500 $ (5,522 ) Total federal and state income taxes $ 18,369 $ 79,294 $ 76,974 Items charged or credited directly to members’ equity Federal deferred 1,976 106 (1,137 ) State deferred 319 17 (184 ) Total tax expense (benefit) from items charged directly to member’s equity $ 2,295 $ 123 $ (1,321 ) Total federal and state income tax expense $ 20,664 $ 79,417 $ 75,653 The balance of accumulated deferred federal and state income tax assets and liabilities at December 31, 2016 , and 2015 was comprised of the following: (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Depreciation and property basis differences $ (941,166 ) $ (944,675 ) Net operating loss carryforward (362 ) 18 Fuel costs (8,802 ) (7,833 ) Other comprehensive income 8,021 9,878 Regulated operations regulatory liability, net (91,734 ) (90,122 ) Postretirement benefits other than pension 1,288 (3,853 ) Other (35,837 ) (6,944 ) Accumulated deferred federal and state income taxes, net $ (1,068,592 ) $ (1,043,531 ) 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. Management considers it more likely than not that all deferred tax assets will be realized; therefore, no valuation allowance has been recorded. Uncertain Tax Positions Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. At December 31, 2016, and 2015, Cleco and Cleco Power had no interest payable related to uncertain tax positions. The interest payable reflects the amount of interest anticipated to be paid to or received from taxing authorities. These amounts do not include any offset for amounts that may be recovered from customers under the existing rate orders. The amounts expected to be recoverable from Cleco Power’s customers under existing rate orders for settled positions at December 31, 2016, and 2015, are $2.5 million and $1.3 million , respectively. For the years ended December 31, 2016, 2015, and 2014, Cleco and Cleco Power had no interest expense related to uncertain tax positions. At December 31, 2016, and 2015, Cleco had no liability for unrecognized tax benefits. The total liability for unrecognized tax benefits for Cleco at December 31, 2014 is shown in the following table: Cleco (THOUSANDS) LIABILITY FOR UNRECOGNIZED TAX BENEFITS PREDECESSOR Balance, Jan. 1, 2014 $ 5,071 Reduction for tax positions of current period — Additions for tax positions of prior years — Reduction for tax positions of prior years — Reduction for settlement with tax authority (5,071 ) Reduction for lapse of statute of limitations — Balance, Dec. 31, 2014 $ — At December 31, 2016, 2015, and 2014, Cleco Power had no liability for unrecognized tax benefits. The federal income tax years that remain subject to examination by the IRS are 2012, 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. In August 2014, Cleco reached a settlement for tax years 2001 through 2010. In August 2015, Cleco reached a settlement for tax years 2011 through 2013. The favorable impact from the settlement was reflected in various line items in the financial statements. At December 31, 2016, and 2015, Cleco had no liability for uncertain tax positions. The settlement of open tax years could involve the payment of additional taxes, the adjustment of deferred taxes, and/or the recognition of tax benefits, which may have an effect on Cleco’s effective tax rate. Cleco classifies income tax penalties as a component of other expenses. For the years ended December 31, 2016 , and 2015 , no penalties were recognized. For the year ended December 31, 2014 , $0.1 million of penalties was recognized.

Disclosures about Segments

Disclosures about Segments	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Disclosures about Segments	Note 11 — Disclosures about Segments Cleco Cleco’s reportable segment is based on its method of internal reporting, which disaggregates business units by its first-tier subsidiary. As a result of the Coughlin transfer from Evangeline to Cleco Power in March 2014, Midstream no longer meets the requirements to be disclosed as a separate reportable segment. Management determined the retrospective application of this transfer to be quantitatively and qualitatively immaterial when taken as a whole in relation to Cleco Power’s financial statements. As a result, Cleco’s segment reporting disclosures were not retrospectively adjusted to reflect the transfer. For more information, see Note 18 — “Coughlin Transfer.” Beginning in April 2014, the remaining operations of Midstream are included as Other in the following table, along with the holding company, a shared services subsidiary, two transmission interconnection facility subsidiaries, and an investment 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 financial results of Cleco’s segment is 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 SUCCESSOR APR. 13, 2016 - DEC. 31, 2016 PREDECESSOR JAN. 1, 2016 - APR. 12, 2016 (THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL CLECO POWER OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 810,075 $ (7,482 ) $ (1 ) $ 802,592 $ 281,154 $ — $ — $ 281,154 Other operations 50,080 1,482 — 51,562 18,493 587 — 19,080 Electric customer credits (1,149 ) — — (1,149 ) (364 ) — — (364 ) Affiliate revenue 621 35,602 (36,223 ) — 263 15,024 (15,287 ) — Operating revenue, net $ 859,627 $ 29,602 $ (36,224 ) $ 853,005 $ 299,546 $ 15,611 $ (15,287 ) $ 299,870 Depreciation and amortization $ 102,444 $ 7,296 $ (1 ) $ 109,739 $ 43,698 $ 377 $ 1 $ 44,076 Merger transaction and commitment costs $ 151,501 $ 23,195 $ — $ 174,696 $ — $ 34,928 $ (16 ) $ 34,912 Interest charges $ 54,606 $ 35,246 $ (86 ) $ 89,766 $ 21,840 $ 295 $ (12 ) $ 22,123 Interest income $ 652 $ 275 $ (87 ) $ 840 $ 208 $ 69 $ (12 ) $ 265 Federal and state income tax expense (benefit) $ 5,376 $ (28,198 ) $ — $ (22,822 ) $ 12,993 $ (9,525 ) $ — $ 3,468 Net income (loss) $ 17,580 $ (41,692 ) $ (1 ) $ (24,113 ) $ 21,548 $ (25,508 ) $ — $ (3,960 ) Additions to property, plant, and equipment $ 143,790 $ 654 $ — $ 144,444 $ 42,353 $ 39 $ — $ 42,392 Equity investment in investee $ 18,672 $ — $ — $ 18,672 Goodwill $ 1,490,797 $ — $ — $ 1,490,797 Total segment assets $ 5,758,245 $ 614,959 $ (30,060 ) $ 6,343,144 PREDECESSOR (THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 1,142,389 $ — $ — $ 1,142,389 Other operations 67,109 2,078 (1 ) 69,186 Electric customer credits (2,173 ) — — (2,173 ) Affiliate revenue 1,142 57,323 (58,465 ) — Operating revenue, net $ 1,208,467 $ 59,401 $ (58,466 ) $ 1,209,402 Depreciation and amortization $ 147,839 $ 1,739 $ 1 $ 149,579 Merger transaction costs $ — $ 4,592 $ (1 ) $ 4,591 Interest charges $ 76,560 $ 1,149 $ 282 $ 77,991 Interest income $ 725 $ (111 ) $ 281 $ 895 Federal and state income tax expense (benefit) $ 79,294 $ (1,590 ) $ — $ 77,704 Net income (loss) $ 141,350 $ (7,681 ) $ — $ 133,669 Additions to property, plant, and equipment $ 156,357 $ 462 $ — $ 156,819 Equity investment in investee $ 16,822 $ — $ — $ 16,822 Total segment assets $ 4,233,337 $ 21,471 $ 68,546 $ 4,323,354 PREDECESSOR (THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 1,225,960 $ — $ — $ 1,225,960 Tolling operations — 5,467 (5,467 ) — Other operations 64,893 2,163 (1 ) 67,055 Electric customer credits (23,530 ) — — (23,530 ) Affiliate revenue 1,326 56,031 (57,357 ) — Operating revenue, net $ 1,268,649 $ 63,661 $ (62,825 ) $ 1,269,485 Depreciation and amortization $ 144,026 $ 2,479 $ — $ 146,505 Merger transaction costs $ — $ 17,848 $ — $ 17,848 Interest charges $ 74,673 $ (1,538 ) $ 471 $ 73,606 Interest income $ 1,707 $ (410 ) $ 471 $ 1,768 Federal and state income tax expense (benefit) $ 76,974 $ (9,858 ) $ — $ 67,116 Net income (loss) $ 154,316 $ 424 $ (1 ) $ 154,739 Additions to property, plant, and equipment $ 206,607 $ 1,029 $ — $ 207,636 Equity investment in investees $ 14,532 $ 8 $ — $ 14,540 Total segment assets $ 4,232,942 $ 248,043 $ (112,567 ) $ 4,368,418 Cleco Power Cleco Power is a vertically integrated, regulated electric utility operating within Louisiana and Mississippi and is viewed as one unit by management. Discrete financial reports are prepared only at the company level.

Regulation and Rates

Regulation and Rates	12 Months Ended
	Dec. 31, 2016
Regulated Operations [Abstract]
Regulation and Rates	Note 12 — 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. A binding FERC order on the second ROE complaint is expected in the second quarter of 2017. As of December 31, 2016 , Cleco Power h ad $3.3 million a ccrued for ROE reductions, including accrued interest. On February 13, 2017, $1.2 million of refunds relating to the first complaint were submitted to MISO . For more information on the ROE complaint, see Note 15 — “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% 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 ending 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. In October 2015, Cleco Power filed its monitoring report for the 12-month period ended June 30, 2015, which indicated that $0.2 million was due to be returned to eligible customers. On July 27, 2016, the LPSC Staff issued their report indicating agreement with Cleco Power’s refund calculation for the 12-month period ended June 30, 2015. The $0.2 million was refunded to eligible customers in September 2016. 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 December 28, 2016, Cleco Power received its first set of data requests pertaining to the monitoring report and has filed responses. On February 2, 2017, Cleco Power received a second set of data requests. Cleco Power is in the process of preparing responses to these requests. 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 December 31, 2016 , Cleco Power had issued $121.5 million of customer rate credits. Also included in the Merger Commitments were $2.5 million of contributions for economic development for Louisiana state and local organizations to be disbursed over five years, an additional $7.0 million one-time contribution for economic development in Cleco Power’s service territory to be administered by the LED, and $6.0 million of charitable contributions to be disbursed over five years. In 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 is 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 December 31, 2016 , Cleco Power had $0.9 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 quarter of 2017.

Variable Interest Entities

Variable Interest Entities	12 Months Ended
	Dec. 31, 2016
Variable Interest Entities [Abstract]
Variable Interest Entities	Note 13 — 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 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 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 December 31, 2016 , consisted of its equity investment of $18.7 million . During 2016 , Cleco Power made $2.5 million of cash contributions to its equity investment in Oxbow as a result of the expected transition from the Dolet Hills mine to the Oxbow mine in the second quarter of 2017. During 2016, Cleco Power received $0.6 million from Oxbow as a return of investment. The following table presents the components of Cleco Power’s equity investment in Oxbow: INCEPTION TO DATE (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Purchase price $ 12,873 $ 12,873 Cash contributions 6,399 3,949 Dividend received (600 ) — Total equity investment in investee $ 18,672 $ 16,822 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 DEC. 31, 2016 AT DEC. 31, 2015 Oxbow’s net assets/liabilities $ 37,345 $ 33,645 Cleco Power’s 50% equity $ 18,672 $ 16,822 Cleco Power’s maximum exposure to loss $ 18,672 $ 16,822 The following tables contain summarized financial information for Oxbow: (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current assets $ 886 $ 2,794 Property, plant, and equipment, net 25,864 23,749 Other assets 10,971 7,220 Total assets $ 37,721 $ 33,763 Current liabilities $ 376 $ 118 Partners’ capital 37,345 33,645 Total liabilities and partners’ capital $ 37,721 $ 33,763 FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Operating revenue $ 5,459 $ 3,991 $ 2,248 Operating expenses 5,459 3,991 2,248 Income before taxes $ — $ — $ — Oxbow’s property, plant, and equipment, net consists of land and lignite reserves. The lignite reserves are intended to be used to provide fuel to the Dolet Hills Power Station. DHLC mines the lignite reserves at Oxbow through the Amended Lignite Mining Agreement. Oxbow has no third-party agreements, guarantees, or other third-party commitments that contain obligations affecting Cleco Power’s investment in Oxbow.

Operating Leases

Operating Leases	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Operating Leases	Note 14 — Operating Leases Cleco maintains operating leases in its ordinary course of business activities. For the years ended December 31, 2016 , 2015 , and 2014 , operating lease expense of $9.0 million , $9.4 million , and $9.4 million was recognized, respectively. The following table is a summary of expected operating lease payments for Cleco and Cleco Power: (THOUSANDS) CLECO HOLDINGS CLECO POWER TOTAL Year ending Dec. 31, 2017 $ 315 $ 6,505 $ 6,820 2018 313 2,939 3,252 2019 — 2,823 2,823 2020 — 2,801 2,801 2021 — 2,396 2,396 Thereafter — 3,301 3,301 Total operating lease payments $ 628 $ 20,765 $ 21,393 Cleco Power leases utility systems from two municipalities and one non-municipal public body. The first municipal lease has a term of 10 years and expires on August 11, 2021. The second municipal lease has a term of 10 years and expires on May 13, 2018. The non-municipal lease has a term of 27 years and expires on July 31, 2039. Each utility system lease contains provisions for extensions. Cleco Power has leases for 231 railcars for coal transportation. One lease for 115 railcars expires on March 31, 2021. The other lease for 116 railcars expires on March 31, 2017 and management is evaluating future options. Cleco Power pays a monthly rental fee per car. The railcar leases do not contain contingent rent payments. Cleco Power leases three towboats to push the barges that deliver solid fuels to the plant site. The lease agreement for these towboats expires on August 31, 2017. Cleco Power pays a fixed amount for the towboats that is adjusted annually. Cleco and Cleco Power’s remaining leases provide for office and operating facilities, office equipment, tower rentals, and vehicles.

Litigation, Other Commitments a

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	12 Months Ended
	Dec. 31, 2016
Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees [Abstract]
Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees Litigation Devil’s Swamp In October 2007, Cleco received a Special Notice for Remedial Investigation and Feasibility Study (RI/FS) from the EPA pursuant to the Comprehensive Environmental Response, Compensation, and Liability Act of 1980 (also known as the Superfund statute) for a facility known as the Devil’s Swamp Lake site located just northwest of Baton Rouge, Louisiana. The special notice requested that Cleco and Cleco Power, along with many other listed potentially responsible parties (PRP), enter into negotiations with the EPA for the performance of an RI/FS at the Devil’s Swamp Lake site. The EPA identified Cleco as one of many companies that sent PCB wastes for disposal to the site. The EPA proposed to add the Devil’s Swamp Lake site to the National Priorities List on March 8, 2004, based on the release of PCBs to fisheries and wetlands located on the site, but no final listing decision has yet been made. The PRPs began discussing a potential proposal to the EPA in February 2008. The EPA issued a Unilateral Administrative Order to two PRP’s, Clean Harbors, Inc. and Baton Rouge Disposal, to conduct an RI/FS in December 2009. The Tier 1 part of the study was completed in June 2012. Field activities for the Tier 2 investigation were completed in July 2012. The draft Tier 2 remedial investigation report was submitted in December 2014. In 2015, remedial investigation activities included the collection and analysis of sediment, crawfish, and fish tissue samples. After reviewing the sample analysis, in August 2015, the Louisiana Department of Health and Hospitals updated the advisory for the area to advise that fish and crawfish from the area should not be eaten. The final Tier 2 remedial investigation report was made public in December 2015. Currently, the study/remedy selection task continues, and there is no record of a decision. Therefore, management is unable to determine how significant Cleco’s share of the costs associated with the RI/FS and possible response action at the site, if any, may be and whether this will have a material impact on the results of operations, financial condition, or cash flows of the Registrants. Merger In connection with the Merger, four actions were filed in the Ninth Judicial District Court for Rapides Parish, Louisiana and three actions were filed in the Civil District Court for Orleans Parish, Louisiana. The petitions in each action generally alleged, among other things, that the members of the 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 names Cleco Corporation, its directors, Cleco Partners, and Merger Sub as defendants. The Consolidated Amended Petition alleges, 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 alleges 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 alleges, among other things, that 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. A briefing schedule has not yet been set. 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 and are otherwise without merit and that it has substantial meritorious defenses to the claims alleged by Gulf Coast. 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. Management expects the report to be approved by the LPSC in the second quarter of 2017. Cleco Power currently has FAC filings for 2016 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 currently has EAC filings for 2016 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 current 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. In December 2015, an ALJ issued an initial decision recommending a 10.32% ROE. On September 29, 2016, FERC issued a Final Order confirming the ALJ’s recommendation of 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. A binding FERC order on the second ROE complaint is expected in the second quarter of 2017. 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 proceeding. As of December 31, 2016, Cleco Power had $3.3 million accrued for a reduction to the ROE, including accrued interest. On February 13, 2017, $1.2 million of refunds relating to the first complaint were submitted to MISO . 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 December 31, 2016 , 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 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 December 31, 2016, 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 December 31, 2016, 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, 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. Previously, Cleco Power recorded a liability of $3.8 million related to the amended agreement with an offsetting regulatory asset. Management determined that it does not expect to be required to pay DHLC under this guarantee. As a result of this determination, the liability and the offsetting regulatory asset were remeasured to zero during the second quarter of 2016. 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. Long-Term Purchase Obligations Cleco Holdings had no unconditional long-term purchase obligations at December 31, 2016 . Cleco Power has several unconditional long-term purchase obligations related to the purchase of petroleum coke, limestone, and energy delivery facilities. The aggregate amount of payments required under such obligations at December 31, 2016 , is as follows: YEAR ENDING DEC. 31, (THOUSANDS) 2017 $ 56,482 2018 14,905 2019 3,688 Total long-term purchase obligations $ 75,075 Payments under these agreements for the years ended December 31, 2016 , 2015 , and 2014 were $72.9 million , $89.7 million , and $90.4 million , respectively. 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 Consolidated Balance Sheets in the line item titled Tax credit fund investment, net. At December 31, 2016, and 2015 the amount of the liability component contained in the net asset was $0.6 million and zero , respectively. The liability at December 31, 2016, is expected to be paid in the first quarter of 2017. The amount of tax benefits delivered in excess of capital contributions as of December 31, 2016 , was $17.3 million . The amount of tax benefits delivered but not utilized as of December 31, 2016 , was $116.2 million and is reflected as a deferred tax asset. By using the cost method for investments, the gross investment amortization expense will be recognized over a ten -year period, with two years remaining under the new amendment. The basis of the investment is reduced by the grants received under Section 1603 of the ARRA, which allow certain projects to receive a federal grant in lieu of tax credits, and other cash. Periodic amortization of the investment and the deferred taxes generated by the basis reduction temporary difference are included as components of income tax expense. Fuel Transportation Agreement In October 2007, Cleco Power entered into an agreement with Savage Services that met the accounting definition of a capital lease for barges in order to transport petroleum coke and limestone to Madison Unit 3. On December 28, 2012, Cleco Power entered into an amended agreement for 42 dedicated barges. The amended agreement continues to meet the accounting definition of a capital lease. Under the amended agreement, the barge lease rate contains both fixed and variable components, of which the latter is adjusted annually per the Producer Price Index (PPI) for executory costs. The initial term of this agreement is from the date of the amendment until August 31, 2017. The term of this agreement will automatically renew for successive periods of two years each unless written notice is provided by either party. The amended agreement contains a provision for early termination upon the occurrence of any one of four specified cancellation events. Cleco is evaluating future options related to its fuel transportation agreement with Savage Services. Under both the original agreement and the amended agreement, if the barges are idle, the lessor is required to attempt to sublease the barges to third parties, with the revenue reducing Cleco Power’s lease payment. During the year ended December 31, 2016 , Cleco Power paid approximately $3.7 million in lease payments and received less than $0.1 million revenue from subleases. During the year ended December 31, 2015 , Cleco Power paid approximately $3.7 million in lease payments and received $ 0.5 million in revenue from subleases. The following is an analysis of leased property under capital leases by major classes: AT DEC. 31, CLASSES OF PROPERTY (THOUSANDS) 2016 2015 Barges $ 11,350 $ 11,350 Less: accumulated amortization 9,729 7,296 Net capital leases $ 1,621 $ 4,054 The following is a schedule by years of future minimum lease payments under capital leases together with the present value of the net minimum lease payments as of December 31, 2016 : (THOUSANDS) Year ending December 31, 2017 $ 2,480 Less: executory costs 620 Net minimum lease payments 1,860 Less: amount representing interest 41 Present value of net minimum lease payments $ 1,819 Current liabilities $ 1,819 During the years ended December 31, 2016 , and 2015 , Cleco Power incurred immaterial amounts of contingent rent under the barge agreement related to the increase in the PPI. Other Cleco has accrued for liabilities related to third parties, employee medical benefits, and AROs. For more information on AROs, see Note 2 — “Summary of Significant Accounting Policies — AROs” and Note 4 — “Regulatory Assets and Liabilities — 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 rating 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. Any downgrade of credit ratings would result in additional fees and higher interest rates under its bank credit facilities and, potentially, other debt agreements. Changes in the regulatory environment or market forces could cause Cleco to determine its assets have suffered an other-than-temporary decline in value, whereby an impairment would be required and Cleco’s financial condition could be materially adversely affected. Cleco Power is a participant in the MISO market. Energy prices in the MISO market are based on LMP, which includes a component directly related to congestion on the transmission system. Pricing zones with greater transmission congestion may have a higher LMP. Physical transmission constraints present in the MISO market could increase energy costs within Cleco Power’s pricing zones. Cleco Power uses FTRs to mitigate transmission congestion risk. Changes to anticipated transmission paths may result in an unexpected increase in energy costs to Cleco Power.

Affiliate Transactions

Affiliate Transactions	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Affiliate Transactions	Note 16 — Affiliate Transactions Cleco Cleco has entered into service agreements with affiliates to receive and to provide goods and professional services. Goods and services received by Cleco primarily involve services provided by Support Group. Support Group provides joint and common administrative support services in the areas of information technology; finance, cash management, accounting, tax, and auditing; human resources; public relations; project consulting; risk management; strategic and corporate development; legal, ethics, and regulatory compliance; facilities management; supply chain and inventory management; and other administrative services. In March, 2014, Coughlin was transferred to Cleco Power. Until the transfer in 2014, Midstream provided electric power plant operations and maintenance expertise, primarily to Evangeline. Cleco is charged the higher of management’s estimated fair market value or fully loaded costs for goods and services provided by Cleco Power. Cleco, with the exception of Support Group, charges Cleco Power the lower of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements. Support Group charges only fully loaded costs. All charges and revenues from consolidated affiliates were eliminated in Cleco’s Consolidated Statements of Income for the years ending December 31, 2016 , 2015 , and 2014 . At December 31, 2016 , Cleco Holdings had accounts receivable of less than $0.1 million due from Cleco Group in relation to merger costs paid on behalf of Cleco Group. At December 31, 2016 , Cleco Holdings had no accounts payable due to Cleco Group. At December 31, 2015 , Cleco had no affiliate balances that were payable to or receivable from non-consolidated affiliates. During the successor period April 13, 2016, through December 31, 2016, Cleco Holdings received $100.7 million of equity contributions from Cleco Group and made $88.8 million of distribution payments to Cleco Group. Cleco Power Cleco Power has entered into service agreements with affiliates to receive and to provide goods and professional services. Charges from affiliates included in Cleco Power’s Consolidated Statements of Income primarily involve services provided by Support Group in accordance with service agreements. In March 2014, Coughlin was transferred to Cleco Power. Prior to the transfer, charges from affiliates also included power purchased from Evangeline. Support Group provides joint and common administrative support services in the areas of information technology; finance, cash management, accounting, tax, and auditing; human resources; public relations; project consulting; risk management; strategic and corporate development; legal, ethics, and regulatory compliance; facilities management; supply chain and inventory management; and other administrative services. For information on the transfer of Coughlin, see Note 18 — “Coughlin Transfer.” With the exception of Support Group, affiliates charge Cleco Power the lower of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements. Support Group charges only fully loaded costs. The following table is a summary of charges from each affiliate included in Cleco Power’s Consolidated Statements of Income: FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Support Group Other operations $ 46,116 $ 53,079 $ 50,801 Maintenance $ 2,255 $ 1,807 $ 2,091 Taxes other than income taxes $ 10 $ (3 ) $ (9 ) Other expenses $ 106 $ 403 $ 339 Evangeline Purchased power expense $ — $ — $ 5,467 The majority of the services provided by Cleco Power relates to the lease of office space to Support Group. Cleco Power charges affiliates the higher of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements. The following table is a summary of revenue received from affiliates included in Cleco Power’s Consolidated Statements of Income: FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Affiliate revenue Support Group $ 884 $ 1,142 $ 1,322 Evangeline — — 4 Total affiliate revenue $ 884 $ 1,142 $ 1,326 Other income Cleco Holdings $ 19 $ 3 $ 30 Support Group — — 10 Evangeline — — 9 Diversified Lands — 10 14 Perryville 6 — 5 Attala 6 — 5 Total other income $ 31 $ 13 $ 73 Total $ 915 $ 1,155 $ 1,399 Cleco Power had the following affiliate receivable and payable balances associated with the service agreements: AT DEC. 31, 2016 AT DEC. 31, 2015 (THOUSANDS) ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE Cleco Holdings $ 3 $ 119 $ 653 $ 564 Support Group 1,402 7,071 1,254 6,034 Other (1) 1 — 1 — Total $ 1,406 $ 7,190 $ 1,908 $ 6,598 (1) Represents Attala and Perryville in 2016 and Attala, Diversified Lands, and Perryville in 2015. During 2016 , 2015 , and 2014 , Cleco Power made $110.0 million , $135.0 million , and $115.0 million of distribution payments to Cleco Holdings, respectively. During 2016, Cleco Power received equity contributions from Cleco Holdings of $50.0 million cash. Cleco Power received no equity contributions from Cleco Holdings in 2015 and received a $138.1 million non-cash equity contribution relating to the transfer of Coughlin in 2014. 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 Power’s affiliates is transferred with a like amount of assets to Cleco Power monthly. The following table shows the expense of the pension plan related to Cleco Power’s affiliates for the years ended 2016 and 2015 : FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 Support Group $ 1,771 $ 2,055 Note 18 — Coughlin Transfer In October 2012, Cleco Power announced that Evangeline was the winning bidder in Cleco Power’s 2012 long-term RFP for up to 800 MW to meet long-term capacity and energy needs. In December 2012, Cleco Power and Evangeline executed definitive agreements to transfer ownership and control of Coughlin from Evangeline to Cleco Power. In March 2014, Coughlin was transferred to Cleco Power with a net book value of $176.0 million . Cleco Power finalized the rate treatment of Coughlin as part of its FRP extension proceeding before the LPSC in June 2014.

Intangible Assets and Goodwill

Intangible Assets and Goodwill	12 Months Ended
	Dec. 31, 2016
Goodwill and Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets Disclosure	Note 17 — Intangible Assets and Goodwill During 2008, Cleco Katrina/Rita acquired a $177.5 million intangible asset which includes $176.0 million for the right to bill and collect storm recovery charges from customers of Cleco Power and $1.5 million of financing costs. This intangible asset is expected to have a life of 12 years , but may have a life of up to 15 years depending on the time period required to collect the required amount from Cleco Power’s customers. The intangible asset’s expected amortization expense is based on the estimated collections from Cleco Power’s customers. At the end of its life, the asset will have no residual value. At the date of the Merger, the gross balance of the Cleco Katrina/Rita intangible asset for Cleco was adjusted to be net of accumulated amortization, as no accumulated amortization existed on the date of the Merger. During the years ended December 31, 2016 , 2015 , and 2014 , Cleco Katrina/Rita recognized amortization expense of $16.5 million , $15.7 million , and $15.4 million , respectively, based on actual collections. As a result of the Merger, fair value adjustments were recorded on Cleco’s Consolidated Balance Sheet for the valuation of the Cleco trade name and long-term wholesale power supply agreements. At the end of their life, these intangible assets will have no residual value. The trade name intangible asset is being amortized over its estimated economic useful life of 20 years . For the successor period April 13, 2016, through December 31, 2016 , Cleco recognized amortization expense of $0.2 million on the trade name intangible asset. The intangible assets related to the power supply agreements are being amortized over the remaining life of each applicable contract ranging between 2 years and 19 years . For the successor period April 13, 2016, through December 31, 2016 , Cleco recognized a reduction of revenue of $7.5 million on the intangible assets for the power supply agreements. The following tables summarize the balances for intangible assets subject to amortization for Cleco and Cleco Power as of December 31, 2016 , and 2015 : Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 70,594 $ 177,537 Power supply agreements 86,726 — Trade name 5,100 — Gross carrying amount 162,420 177,537 Accumulated amortization (19,786 ) (102,574 ) Net intangible assets subject to amortization $ 142,634 $ 74,963 Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 177,537 $ 177,537 Accumulated amortization (119,064 ) (102,574 ) Net intangible assets subject to amortization $ 58,473 $ 74,963 The following tables summarize the amortization expense related to intangible assets expected to be recognized in Cleco and Cleco Power’s Statements of Income: Cleco EXPECTED AMORTIZATION EXPENSE (THOUSAND) For the year ending Dec. 31, 2017 $ 28,704 2018 $ 29,564 2019 $ 31,087 2020 $ 9,935 2021 $ 9,935 Thereafter $ 33,409 Cleco Power EXPECTED AMORTIZATION EXPENSE (THOUSANDS) For the year ending Dec. 31, 2017 $ 18,009 2018 $ 19,312 2019 $ 21,152 On April 13, 2016, in connection with the completion of the Merger, Cleco recognized goodwill of $1.49 billion . Management has assigned goodwill to Cleco’s reportable segment, Cleco Power. For more information about Cleco’s policy on goodwill, see Note 2 — “Summary of Significant Accounting Policies — Goodwill.” For more information about the Merger related adjustments, see Note 3 — “Business Combinations.”

Coughlin Transfer

Coughlin Transfer	12 Months Ended
	Dec. 31, 2016
Coughlin Transfer [Abstract]
Coughlin Transfer	Note 16 — Affiliate Transactions Cleco Cleco has entered into service agreements with affiliates to receive and to provide goods and professional services. Goods and services received by Cleco primarily involve services provided by Support Group. Support Group provides joint and common administrative support services in the areas of information technology; finance, cash management, accounting, tax, and auditing; human resources; public relations; project consulting; risk management; strategic and corporate development; legal, ethics, and regulatory compliance; facilities management; supply chain and inventory management; and other administrative services. In March, 2014, Coughlin was transferred to Cleco Power. Until the transfer in 2014, Midstream provided electric power plant operations and maintenance expertise, primarily to Evangeline. Cleco is charged the higher of management’s estimated fair market value or fully loaded costs for goods and services provided by Cleco Power. Cleco, with the exception of Support Group, charges Cleco Power the lower of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements. Support Group charges only fully loaded costs. All charges and revenues from consolidated affiliates were eliminated in Cleco’s Consolidated Statements of Income for the years ending December 31, 2016 , 2015 , and 2014 . At December 31, 2016 , Cleco Holdings had accounts receivable of less than $0.1 million due from Cleco Group in relation to merger costs paid on behalf of Cleco Group. At December 31, 2016 , Cleco Holdings had no accounts payable due to Cleco Group. At December 31, 2015 , Cleco had no affiliate balances that were payable to or receivable from non-consolidated affiliates. During the successor period April 13, 2016, through December 31, 2016, Cleco Holdings received $100.7 million of equity contributions from Cleco Group and made $88.8 million of distribution payments to Cleco Group. Cleco Power Cleco Power has entered into service agreements with affiliates to receive and to provide goods and professional services. Charges from affiliates included in Cleco Power’s Consolidated Statements of Income primarily involve services provided by Support Group in accordance with service agreements. In March 2014, Coughlin was transferred to Cleco Power. Prior to the transfer, charges from affiliates also included power purchased from Evangeline. Support Group provides joint and common administrative support services in the areas of information technology; finance, cash management, accounting, tax, and auditing; human resources; public relations; project consulting; risk management; strategic and corporate development; legal, ethics, and regulatory compliance; facilities management; supply chain and inventory management; and other administrative services. For information on the transfer of Coughlin, see Note 18 — “Coughlin Transfer.” With the exception of Support Group, affiliates charge Cleco Power the lower of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements. Support Group charges only fully loaded costs. The following table is a summary of charges from each affiliate included in Cleco Power’s Consolidated Statements of Income: FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Support Group Other operations $ 46,116 $ 53,079 $ 50,801 Maintenance $ 2,255 $ 1,807 $ 2,091 Taxes other than income taxes $ 10 $ (3 ) $ (9 ) Other expenses $ 106 $ 403 $ 339 Evangeline Purchased power expense $ — $ — $ 5,467 The majority of the services provided by Cleco Power relates to the lease of office space to Support Group. Cleco Power charges affiliates the higher of management’s estimated fair market value or fully loaded costs for goods and services provided in accordance with service agreements. The following table is a summary of revenue received from affiliates included in Cleco Power’s Consolidated Statements of Income: FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Affiliate revenue Support Group $ 884 $ 1,142 $ 1,322 Evangeline — — 4 Total affiliate revenue $ 884 $ 1,142 $ 1,326 Other income Cleco Holdings $ 19 $ 3 $ 30 Support Group — — 10 Evangeline — — 9 Diversified Lands — 10 14 Perryville 6 — 5 Attala 6 — 5 Total other income $ 31 $ 13 $ 73 Total $ 915 $ 1,155 $ 1,399 Cleco Power had the following affiliate receivable and payable balances associated with the service agreements: AT DEC. 31, 2016 AT DEC. 31, 2015 (THOUSANDS) ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE Cleco Holdings $ 3 $ 119 $ 653 $ 564 Support Group 1,402 7,071 1,254 6,034 Other (1) 1 — 1 — Total $ 1,406 $ 7,190 $ 1,908 $ 6,598 (1) Represents Attala and Perryville in 2016 and Attala, Diversified Lands, and Perryville in 2015. During 2016 , 2015 , and 2014 , Cleco Power made $110.0 million , $135.0 million , and $115.0 million of distribution payments to Cleco Holdings, respectively. During 2016, Cleco Power received equity contributions from Cleco Holdings of $50.0 million cash. Cleco Power received no equity contributions from Cleco Holdings in 2015 and received a $138.1 million non-cash equity contribution relating to the transfer of Coughlin in 2014. 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 Power’s affiliates is transferred with a like amount of assets to Cleco Power monthly. The following table shows the expense of the pension plan related to Cleco Power’s affiliates for the years ended 2016 and 2015 : FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 Support Group $ 1,771 $ 2,055 Note 18 — Coughlin Transfer In October 2012, Cleco Power announced that Evangeline was the winning bidder in Cleco Power’s 2012 long-term RFP for up to 800 MW to meet long-term capacity and energy needs. In December 2012, Cleco Power and Evangeline executed definitive agreements to transfer ownership and control of Coughlin from Evangeline to Cleco Power. In March 2014, Coughlin was transferred to Cleco Power with a net book value of $176.0 million . Cleco Power finalized the rate treatment of Coughlin as part of its FRP extension proceeding before the LPSC in June 2014.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	12 Months Ended
	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Loss	Note 19 — Accumulated Other Comprehensive Loss The components of accumulated other comprehensive loss are summarized in the following tables for Cleco and Cleco Power. All amounts are reported net of income taxes. Amounts in parentheses indicate debits. Cleco (THOUSANDS) POSTRETIREMENT BENEFIT NET (LOSS) GAIN NET (LOSS) GAIN ON CASH FLOW HEDGES TOTAL AOCI PREDECESSOR Balances, Dec. 31, 2013 $ (19,725 ) $ (6,151 ) $ (25,876 ) Other comprehensive loss before reclassifications Postretirement benefit adjustments incurred during the year (9,022 ) — (9,022 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 2,021 — 2,021 Reclassification of net loss to interest charges — 212 212 Net current-period other comprehensive (loss) income (7,001 ) 212 (6,789 ) Balances, Dec. 31, 2014 $ (26,726 ) $ (5,939 ) $ (32,665 ) Other comprehensive income before reclassifications Postretirement benefit adjustments incurred during the year 2,790 — 2,790 Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 3,079 — 3,079 Reclassification of net loss to interest charges — 211 211 Net current-period other comprehensive income 5,869 211 6,080 Balances, Dec. 31, 2015 $ (20,857 ) $ (5,728 ) $ (26,585 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 587 — 587 Reclassification of net loss to interest charges — 60 60 Net current-period other comprehensive income 587 60 647 Balances, Apr. 12, 2016 $ (20,270 ) $ (5,668 ) $ (25,938 ) SUCCESSOR (1) Balances, Apr. 13, 2016 $ — $ — $ — Other comprehensive income before reclassifications Postretirement benefit adjustments incurred during the year 2,304 — 2,304 Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net gain (804 ) — (804 ) Net current-period other comprehensive income 1,500 — 1,500 Balances, Dec. 31, 2016 $ 1,500 $ — $ 1,500 (1) As a result of the Merger, AOCI was reduced to zero on April 13, 2016, as required by acquisition accounting. Cleco Power (THOUSANDS) POSTRETIREMENT BENEFIT NET (LOSS) GAIN NET (LOSS) GAIN ON CASH FLOW HEDGES TOTAL AOCI Balances, Dec. 31, 2013 $ (9,026 ) $ (6,151 ) $ (15,177 ) Other comprehensive loss before reclassifications Postretirement benefit adjustments incurred during the year (3,344 ) — (3,344 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 1,021 — 1,021 Reclassification of net loss to interest charges — 212 212 Net current-period other comprehensive (loss) income (2,323 ) 212 (2,111 ) Balances, Dec. 31, 2014 $ (11,349 ) $ (5,939 ) $ (17,288 ) Other comprehensive loss before reclassifications Postretirement benefit adjustments incurred during the year (1,232 ) — (1,232 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 1,217 — 1,217 Reclassification of net loss to interest charges — 211 211 Net current-period other comprehensive (loss) income (15 ) 211 196 Balances, Dec. 31, 2015 $ (11,364 ) $ (5,728 ) $ (17,092 ) Other comprehensive income before reclassifications Postretirement benefit adjustments incurred during the year 3,913 — 3,913 Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss (454 ) — (454 ) Reclassification of net loss to interest charges — 211 211 Net current-period other comprehensive income 3,459 211 3,670 Balances, Dec. 31, 2016 $ (7,905 ) $ (5,517 ) $ (13,422 )

Miscellaneous Financial Informa

Miscellaneous Financial Information (Unaudited)	12 Months Ended
	Dec. 31, 2016
Quarterly Financial Information Disclosure [Abstract]
Miscellaneous Financial Information (Unaudited)	Note 20 — Miscellaneous Financial Information (Unaudited) Cleco Quarterly information for Cleco for 2016 and 2015 is shown in the following tables: 2016 PREDECESSOR SUCCESSOR 1ST QUARTER 2ND QUARTER 2ND QUARTER 3RD 4TH QUARTER (THOUSANDS) APR. 1 - APR. 12 APR. 13 - JUNE 30 Operating revenue, net $ 266,968 $ 32,903 $ 243,502 $ 342,860 $ 266,642 Operating income (loss) $ 50,192 $ (29,832 ) $ (110,148 ) $ 93,143 $ 53,299 Net income (loss) $ 19,368 $ (23,328 ) $ (81,914 ) $ 39,621 $ 18,180 Contribution from member $ — $ — $ 100,720 $ — $ — Distributions to member $ — $ — $ 28,000 $ 28,000 $ 32,765 2015 PREDECESSOR (THOUSANDS) 1ST QUARTER 2ND QUARTER 3RD QUARTER 4TH QUARTER Operating revenue, net $ 295,457 $ 289,074 $ 345,468 $ 279,403 Operating income $ 62,722 $ 69,884 $ 102,572 $ 52,162 Net income $ 26,922 $ 30,234 $ 54,663 $ 21,850 Cleco Power Quarterly information for Cleco Power for 2016 and 2015 is shown in the following tables: 2016 (THOUSANDS) 1ST QUARTER 2ND QUARTER 3RD QUARTER 4TH QUARTER Operating revenue, net $ 266,682 $ 278,343 $ 345,131 $ 269,017 Operating income (loss) $ 52,265 $ (81,841 ) $ 99,420 $ 59,156 Net income (loss) $ 20,879 $ (61,229 ) $ 52,572 $ 26,906 Contribution from parent $ — $ 50,000 $ — $ — Distributions to parent $ 25,000 $ 10,000 $ 50,000 $ 25,000 2015 (THOUSANDS) 1ST QUARTER 2ND QUARTER 3RD QUARTER 4TH QUARTER Operating revenue, net $ 295,271 $ 288,885 $ 345,189 $ 279,122 Operating income $ 65,670 $ 70,243 $ 103,966 $ 54,321 Net income $ 28,605 $ 31,813 $ 58,661 $ 22,270 Distributions to parent $ 25,000 $ 35,000 $ 40,000 $ 35,000

Schedule I Financial Statements

Schedule I Financial Statements of Cleco Corporation	12 Months Ended
	Dec. 31, 2016
Condensed Financial Information of Parent Company Only Disclosure [Abstract]
Condensed Financial Information of Parent Company Only Disclosure	CLECO HOLDINGS (Parent Company Only) SCHEDULE I Condensed Statements of Income SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - APR. 12, 2016 FOR THE YEAR ENDED DEC. 31, 2015 FOR THE Operating expenses Administrative and general $ 375 $ 319 $ 1,891 $ 1,534 Merger transaction costs 23,211 34,912 4,591 17,848 Other operating expense (382 ) 624 490 178 Total operating expenses 23,204 35,855 6,972 19,560 Operating loss (23,204 ) (35,855 ) (6,972 ) (19,560 ) Equity income from subsidiaries, net of tax 9,357 21,789 141,636 162,331 Interest, net (35,151 ) (286 ) (1,731 ) (303 ) Other income 1,948 702 17 2,457 Other expense — — (1,142 ) (158 ) (Loss) income before income taxes (47,050 ) (13,650 ) 131,808 144,767 Federal and state income tax benefit (22,937 ) (9,690 ) (1,861 ) (9,972 ) Net (loss) income $ (24,113 ) $ (3,960 ) $ 133,669 $ 154,739 The accompanying notes are an integral part of the Condensed Financial Statements. CLECO HOLDINGS (Parent Company Only) SCHEDULE I Condensed Statements of Comprehensive Income SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - APR. 12, 2016 FOR THE YEAR ENDED DEC. 31, 2015 FOR THE Net (loss) income $ (24,113 ) $ (3,960 ) $ 133,669 $ 154,739 Other comprehensive income (loss), net of tax Postretirement benefits gain (loss) (net of tax expense of $938, $367, and $3,670 and tax benefit of $4,378, respectively) 1,500 587 5,869 (7,001 ) Net gain on cash flow hedges (net of tax expense of $0, $37, $132, and $132, respectively) — 60 211 212 Total other comprehensive income (loss), net of tax 1,500 647 6,080 (6,789 ) Comprehensive (loss) income, net of tax $ (22,613 ) $ (3,313 ) $ 139,749 $ 147,950 The accompanying notes are an integral part of the Condensed Financial Statements. CLECO HOLDINGS (Parent Company Only) SCHEDULE I Condensed Balance Sheets SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Assets Current assets Cash and cash equivalents $ 1,377 $ 2,236 Accounts receivable - affiliate 7,070 7,669 Other accounts receivable 395 — Taxes receivable, net — 14,746 Cash surrender value of trust-owned life insurance policies 57,207 53,821 Total current assets 66,049 78,472 Equity investment in subsidiaries 3,223,920 1,516,310 Tax credit fund investment, net 11,888 13,741 Accumulated deferred federal and state income taxes, net 140,577 123,690 Other deferred charges 1,351 — Total assets $ 3,443,785 $ 1,732,213 Liabilities and member's equity/shareholders’ equity Liabilities Current liabilities Accounts payable $ 3,424 $ 908 Accounts payable - affiliate 14,521 5,389 Taxes payable, net 13,998 — Other current liabilities 19,566 10,975 Total current liabilities 51,509 17,272 Postretirement benefit obligations 4,280 5,848 Other deferred credits 1,100 587 Long-term debt 1,340,133 33,665 Total liabilities 1,397,022 57,372 Commitments and contingencies (Note 5) Member's equity/Shareholders’ equity Member's equity/Common shareholders’ equity Membership interest/Common stock (1) 2,069,376 456,412 (Accumulated deficit)/Retained earnings (24,113 ) 1,245,014 Accumulated other comprehensive income (loss) 1,500 (26,585 ) Total member's equity/common shareholders’ equity 2,046,763 1,674,841 Total liabilities and member's equity/shareholders’ equity $ 3,443,785 $ 1,732,213 (1) At December 31, 2015, shareholders’ equity included $418.5 million of premium on common stock, $61.1 million of common stock, and $23.2 million of treasury stock. At December 31, 2015, Cleco Holdings had 100,000,000 shares of common stock authorized, 61,058,918 shares of common stock issued, and 60,482,468 shares of common stock outstanding, par value $1 per share. At December 31, 2015, Cleco Holdings had 576,450 shares of treasury stock. The accompanying notes are an integral part of the Condensed Financial Statements. CLECO HOLDINGS (Parent Company Only) SCHEDULE I Condensed Statements of Cash Flows SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - APR. 12, 2016 FOR THE YEAR ENDED DEC. 31, 2015 FOR THE Operating activities Net cash provided by operating activities $ 36,811 $ 34,904 $ 128,909 $ 108,754 Investing activities Contributions to tax credit fund — — (9,966 ) (55,315 ) Return of equity investment in tax credit fund 901 476 2,128 2,579 Contribution to subsidiary (50,000 ) — — — Premiums paid on trust-owned life insurance — — (3,607 ) (2,831 ) Net cash (used in) provided by investing activities (49,099 ) 476 (11,445 ) (55,567 ) Financing activities Draws on credit facility — 3,000 57,000 97,000 Payments on credit facility — (10,000 ) (80,000 ) (45,000 ) Issuance of long-term debt 1,350,000 — — — Repayment of long-term debt (1,350,000 ) — — — Payment of financing costs (3,755 ) — — — Repurchase of common stock — — — (12,449 ) Dividends paid on common stock (572 ) (24,579 ) (97,283 ) (95,044 ) Contribution from member 100,720 — — — Distributions to member (88,765 ) — — — Other financing — — (14 ) — Net cash provided by (used in) financing activities 7,628 (31,579 ) (120,297 ) (55,493 ) Net (decrease) increase in cash and cash equivalents (4,660 ) 3,801 (2,833 ) (2,306 ) Cash and cash equivalents at beginning of period 6,037 2,236 5,069 7,375 Cash and cash equivalents at end of period $ 1,377 $ 6,037 $ 2,236 $ 5,069 Supplementary cash flow information Interest paid, net of amount capitalized $ 26,264 $ 126 $ 130 $ 189 Income taxes paid, net $ 4,263 $ 1 $ 1,464 $ 15,013 Supplementary non-cash investing and financing activity Non-cash contribution to subsidiary, net of tax $ — $ — $ — $ 142,880 Non-cash distribution from subsidiary, net of tax $ — $ — $ 33,661 $ 138,080 The accompanying notes are an integral part of the Condensed Financial Statements. Note 1 — Summary of Significant Accounting Policies The condensed financial statements represent the financial information required by SEC Regulation S-X 5-04 for Cleco Holdings, which requires the inclusion of parent company only financial statements if the restricted net assets of consolidated subsidiaries exceed 25% of total consolidated net assets as of the last day of its most recent fiscal year. As of December 31, 2016 , Cleco Holdings’ restricted net assets of consolidated subsidiaries were $1.09 billion and exceeded 25% of its total consolidated net assets. Cleco Holdings’ only major, first-tier subsidiary is Cleco Power. Cleco Power contains the LPSC-jurisdictional generation, transmission, and distribution electric utility operations serving Cleco’s traditional retail and wholesale customers. Prior to March 2014, when Evangeline owned and operated Coughlin, Midstream was also considered a first-tier subsidiary of Cleco Corporation. Subsequent to the transfer of Coughlin from Evangeline to Cleco Power in March 2014, Midstream was no longer considered a first-tier subsidiary. The accompanying financial statements have been prepared to present the results of operations, financial condition, and cash flows of Cleco Holdings on a stand-alone basis as a holding company. Investments in subsidiaries and other investees are presented using the equity method. These financial statements should be read in conjunction with Cleco’s consolidated financial statements. Note 2 — 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. At the effective time of the Merger, each outstanding share of Cleco Corporation common stock, par value $1.00 per share (other than shares that were owned by Cleco Corporation, Cleco Partners, Merger Sub, or any other direct or indirect wholly owned subsidiary of Cleco Partners or Cleco Corporation), were cancelled and 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. For more information regarding the Merger see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 3 — Business Combinations.” Note 3 — Debt At December 31, 2016 , and 2015 , Cleco Holdings had no short-term debt outstanding. At December 31, 2016 , Cleco Holding’s long-term debt outstanding was $1.34 billion , of which none was due within one year. In connection with the completion of the Merger, on April 13, 2016, Cleco Holdings entered into a $1.35 billion Acquisition Loan Facility. The Acquisition Loan Facility had a three -year term and a rate of LIBOR plus 1.75% or ABR plus 0.75% . In May and June 2016, Cleco Holdings refinanced the Acquisition Loan Facility with a series of other long-term financings described below. On May 17, 2016, Cleco Holdings completed the private sale of $535.0 million of 3.743% senior notes due May 1, 2026, and $350.0 million of 4.973% senior notes due May 1, 2046. On May 24, 2016, Cleco Holdings completed the private sale of $165.0 million of 3.250% senior notes due May 1, 2023. On June 28, 2016, Cleco Holdings entered into a $300.0 million variable rate bank term loan due June 28, 2021. Amounts outstanding under the bank term loan bear interest, at Cleco’s option, at a base rate plus 0.625% or LIBOR plus 1.625% . At December 31, 2016 , the all-in rate was 2.265% , which was based on the LIBOR rate. The proceeds from the issuance and sale of these notes and term loan were used to repay the $1.35 billion Acquisition Loan Facility. Debt issuance costs of $17.7 million were expensed to merger costs in connection with the repayment of the Acquisition Loan Facility. The principal amounts payable under long-term debt agreements for each year through 2021 and thereafter are as follows: (THOUSANDS) Amounts payable under long-term debt arrangements For the year ending Dec. 31, 2017 $ — 2018 $ — 2019 $ — 2020 $ — 2021 $ 300,000 Thereafter $ 1,050,000 At December 31, 2015 , Cleco Holdings had a $250.0 million credit facility. On April 13, 2016, in connection with the completion of the Merger, Cleco Holdings replaced the existing credit facility with a $100.0 million credit facility. The new credit facility has similar terms as the previous facility, including restricted financial covenants, and expires in 2021. At December 31, 2016 , Cleco Holdings had no borrowings outstanding under its $100.0 million credit facility. The borrowing costs under the facility are equal to LIBOR plus 1.75% or ABR plus 0.75% , plus commitment fees of 0.275% . At December 31, 2016 , Cleco Holdings was in compliance with the covenants in its credit facility. Note 4 — Cash Distributions and Equity Contributions Some provisions in Cleco Power’s debt instruments restrict the amount of equity available for distribution to Cleco Holdings by Cleco Power by requiring Cleco Power’s total indebtedness to be less than or equal to 65% of total capitalization. In addition, the Merger Commitments provide for limitations on the amount of distributions that may be paid from Cleco Power to Cleco Holdings, depending on Cleco Power’s common equity ratio and its corporate credit ratings. The following table summarizes the cash distributions Cleco Holdings received from affiliates during 2016 , 2015 , and 2014 : SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE Cleco Power $ 85,000 $ 25,000 $ 135,000 $ 115,000 Perryville 150 200 500 975 Attala 100 125 350 750 Total $ 85,250 $ 25,325 $ 135,850 $ 116,725 During the predecessor period January 1, 2014, through December 31, 2014, Cleco Holdings made a $138.1 million non-cash contribution to Cleco Power related to the transfer of Coughlin from Evangeline to Cleco Power. During the predecessor periods January 1, 2015, through December 31, 2015, and January 1, 2016, through April 12, 2016, Cleco Holdings made no contributions to affiliates. During the successor period April 13, 2016, through December 31, 2016, Cleco Holdings made a contribution of $50.0 million to Cleco Power. During the successor period April 13, 2016, through December 31, 2016, Cleco Holdings received $100.7 million of equity contributions from Cleco Group and made $88.8 million of distribution payments to Cleco Group. Note 5 — Income Taxes Cleco Holdings’ (Parent Company Only) Condensed Statements of Income reflect income tax expense (benefit) for the following line items: SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE YEAR ENDED DEC. 31, 2015 FOR THE Federal and state income tax benefit $ (22,937 ) $ (9,690 ) $ (1,861 ) $ (9,972 ) Equity income from subsidiaries - Federal and state income tax expense $ 115 $ 13,158 $ 79,565 $ 77,088 Note 6 — Commitments and Contingencies For information regarding commitments and contingencies related to Cleco Holdings, see Part II, Item 8, “Financial Statements and Supplementary Data — Notes to the Financial Statements — Note 15 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees.”

Schedule II Valuation and Quali

Schedule II Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2016
Valuation and Qualifying Accounts [Abstract]
Schedule II - Valuation and Qualifying Accounts	CLECO SCHEDULE II VALUATION AND QUALIFYING ACCOUNTS (THOUSANDS) BALANCE AT ADDITIONS TO COSTS AND EXPENSES UNCOLLECTIBLE BALANCE AT END OF PERIOD (1) Allowance for Uncollectible Accounts SUCCESSOR Period Apr. 13, 2016 to Dec. 31, 2016 $ 3,336 $ 4,348 $ 485 $ 7,199 PREDECESSOR Period Jan. 1, 2016 to Apr. 12, 2016 $ 2,674 $ 1,163 $ 501 $ 3,336 Year Ended Dec. 31, 2015 $ 922 $ 2,986 $ 1,234 $ 2,674 Year Ended Dec. 31, 2014 $ 849 $ 1,980 $ 1,907 $ 922 (1) Deducted in the consolidated balance sheet (THOUSANDS) BALANCE AT BEGINNING OF PERIOD ADDITIONS DEDUCTIONS BALANCE AT END OF PERIOD (1) Unrestricted Storm Reserve SUCCESSOR Period Apr. 13, 2016 to Dec. 31, 2016 $ 2,536 $ 71 $ — $ 2,607 PREDECESSOR Period Jan. 1, 2016 to Apr. 12, 2016 $ 2,801 $ — $ 265 $ 2,536 Year Ended Dec. 31, 2015 $ 3,322 $ — $ 521 $ 2,801 Year Ended Dec. 31, 2014 $ 1,236 $ 4,133 $ 2,047 $ 3,322 Restricted Storm Reserve SUCCESSOR Period Apr. 13, 2016 to Dec. 31, 2016 $ 16,515 $ 870 $ — $ 17,385 PREDECESSOR Period Jan. 1, 2016 to Apr. 12, 2016 $ 16,177 $ 338 $ — $ 16,515 Year Ended Dec. 31, 2015 $ 14,916 $ 1,261 $ — $ 16,177 Year Ended Dec. 31, 2014 $ 17,646 $ 1,414 $ 4,144 $ 14,916 (1) Included in the consolidated balance sheet CLECO POWER SCHEDULE II VALUATION AND QUALIFYING ACCOUNTS (THOUSANDS) BALANCE AT ADDITIONS TO COSTS AND EXPENSES UNCOLLECTIBLE BALANCE AT END OF PERIOD (1) Allowance for Uncollectible Accounts Year Ended Dec. 31, 2016 $ 2,674 $ 5,511 $ 986 $ 7,199 Year Ended Dec. 31, 2015 $ 922 $ 2,986 $ 1,234 $ 2,674 Year Ended Dec. 31, 2014 $ 849 $ 1,980 $ 1,907 $ 922 (1) Deducted in the consolidated balance sheet (THOUSANDS) BALANCE AT BEGINNING OF PERIOD ADDITIONS DEDUCTIONS BALANCE AT END OF PERIOD (1) Unrestricted Storm Reserve Year Ended Dec. 31, 2016 $ 2,801 $ 71 $ 265 $ 2,607 Year Ended Dec. 31, 2015 $ 3,322 $ — $ 521 $ 2,801 Year Ended Dec. 31, 2014 $ 1,236 $ 4,133 $ 2,047 $ 3,322 Restricted Storm Reserve Year Ended Dec. 31, 2016 $ 16,177 $ 1,208 $ — $ 17,385 Year Ended Dec. 31, 2015 $ 14,916 $ 1,261 $ — $ 16,177 Year Ended Dec. 31, 2014 $ 17,646 $ 1,414 $ 4,144 $ 14,916 (1) Included in the consolidated balance sheet

Summary of Significant Accoun32

Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Use of Estimates, Policy	The preparation of financial statements requires management to make estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenue and expenses during the reporting period. Actual results could differ from those estimates.
Principles of Consolidation, Policy	The accompanying consolidated financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.
Goodwill, Policy	Goodwill is the excess of the purchase price (consideration transferred and liabilities assumed) over the estimated fair value of net assets of the acquired business and is not subject to amortization. Goodwill will be assessed annually or more often if an event occurs or circumstances change that would indicate the carrying amount may be impaired. If the fair value of Cleco is less than the carrying value, a full valuation of Cleco’s assets and liabilities, conducted as though Cleco were a newly acquired business, would occur. Management has assigned goodwill to Cleco’s reportable segment, Cleco Power.
Intangible Assets, Policy	Intangible assets include Cleco Katrina/Rita’s right to bill and collect storm recovery charges, fair value adjustments for long-term wholesale power supply agreements, and a fair value adjustment for the valuation of the Cleco trade name. The intangible assets are being amortized over their estimated useful lives in a manner that best reflects the economic benefits derived from such assets. Impairment will be tested if there are events or circumstances that indicate that an impairment analysis should be performed. If such an event or circumstance occurs, intangible impairment testing will be performed prior to goodwill impairment testing. Impairment is calculated as the excess of the asset’s carrying amount over its fair value. As a result of the Merger, fair value adjustments were recorded on Cleco’s Consolidated Balance Sheet for the valuation of the Cleco trade name and long-term wholesale power supply agreements. At the end of their life, these intangible assets will have no residual value. The trade name intangible asset is being amortized over its estimated economic useful life of 20 years . This intangible asset is expected to have a life of 12 years , but may have a life of up to 15 years depending on the time period required to collect the required amount from Cleco Power’s customers. The intangible asset’s expected amortization expense is based on the estimated collections from Cleco Power’s customers. At the end of its life, the asset will have no residual value. The intangible assets related to the power supply agreements are being amortized over the remaining life of each applicable contract ranging between 2 years and 19 years .
Statements of Cash Flows, Policy	Cleco and Cleco Power’s Consolidated Statements of Cash Flows are prepared using the indirect method. This method requires adjusting net income to remove the effects of all deferrals and accruals of operating cash receipts and payments and to remove items whose cash effects are related to investing and financing cash flows. Derivatives meeting the definition of an accounting hedge are classified in the same category as the item being hedged.
Regulation, Policy	Cleco Power is subject to regulation by FERC and the LPSC. Cleco Power complies with the accounting policies and practices prescribed by its regulatory commissions. Cleco Power’s retail rates are regulated by the LPSC and its tariffs for transmission services are regulated by FERC. Rates for wholesale power sales are based on market-based rates, pending FERC review of Cleco Power’s generation market power analysis. Cleco Power capitalizes or defers certain costs for recovery from customers and recognizes a liability for amounts expected to be returned to customers based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process. Regulatory assets and liabilities are amortized consistent with the treatment of the related cost in the ratemaking process. Pursuant to this regulatory approval, Cleco has recorded regulatory assets and liabilities. Any future plan adopted by the LPSC for purposes of transitioning utilities from LPSC regulation to retail competition may affect the regulatory assets and liabilities recorded by Cleco if the criteria for the application of the authoritative guidelines for industry regulated operations cannot continue to be met. At this time, Cleco cannot predict whether any legislation or regulation affecting Cleco will be enacted or adopted and, if enacted, what form such legislation or regulation may take. 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 of regulated operations.
Asset Retirement Obligation, Policy	Cleco Power recognizes an ARO when there is a legal obligation under existing or enacted law, statute, written or oral contract, or by legal construction under the doctrine of promissory estoppel to incur costs to remove an asset when the asset is retired. These guidelines also require an ARO which is conditional on a future event to be recorded even if the event has not yet occurred. Cleco Power recognizes AROs at the present value of the projected liability in the period in which it is incurred, if a reasonable estimate of fair value can be made. The liability is then accreted to its present value each accounting period. Cleco Power defers this accretion as a regulatory asset based on its determination that these costs can be collected from customers. Concurrent with the recognition of the liability, these costs are capitalized to the related property, plant, and equipment asset. These capitalized costs are depreciated over the same period as the related property asset. Cleco Power also defers the current depreciation of the asset retirement cost as a regulatory asset. In April 2015, the EPA published the final rule in the Federal Register for regulating the disposal and management of CCRs from coal-fired power plants under Subtitle D of the Resource Conservation and Recovery Act. The Subtitle D option will regulate CCRs in a manner similar to industrial solid waste. The final rule does not require expensive synthetic lining of existing impoundments. At December 31, 2015, based on management’s best estimate of the retirement costs related to this ruling, Cleco Power recorded a $1.0 million increase to its ARO for the retirement of certain ash disposal facilities. All costs of the CCR rule are expected to be recovered from customers in future rates. The actual asset retirement costs related to the CCR rule requirements may vary substantially from the estimates used to record the increased obligation due to the uncertainty about the compliance strategies that will be used and the preliminary nature of available data used to estimate costs. Cleco Power will continue to gather additional data in future periods and will make decisions about compliance strategies and the timing of closure activities. As this additional information becomes available, Cleco Power will update the ARO balance for these changes in estimates. At December 31, 2016, management’s analysis confirmed that no additional adjustments were needed to update Cleco Power’s ARO balance.
Property, Plant, and Equipment, Policy	Property, plant, and equipment consists primarily of regulated utility generation and energy transmission and distribution assets. Regulated assets, utilized primarily for retail operations and electric transmission and distribution, are stated at the cost of construction, which includes certain materials, labor, payroll taxes and benefits, administrative and general costs, and the estimated cost of funds used during construction. Jointly owned assets are reflected in property, plant, and equipment at Cleco Power’s share of the cost to construct or purchase the assets. Cleco’s cost of improvements to property, plant, and equipment is capitalized. Costs associated with repairs and major maintenance projects are expensed as incurred. Cleco capitalizes the cost to purchase or develop software for internal use. Upon retirement or disposition, the cost of Cleco Power’s depreciable plant and the cost of removal, net of salvage value, are charged to accumulated depreciation. For Cleco’s other depreciable assets, upon disposition or retirement, the difference between the net book value of the property and any proceeds received for the property is recorded as a gain or loss on asset disposition on Cleco’s Consolidated Statements of Income. Any cost incurred to remove the asset is charged to expense.
Deferred Project Costs, Policy	Cleco Power defers costs related to the initial stage of a construction project during which time the feasibility of the construction of property, plant, and equipment is being investigated.
Inventories, Policy	Both fuel inventory and materials and supplies are stated at average cost and are issued from stock using the average cost of existing stock. Materials and supplies are recorded when purchased and subsequently charged to expense or capitalized to property, plant, and equipment when installed.
Accounts Receivable, Policy	Accounts receivable are recorded at the invoiced amount and do not bear interest. It is the policy of management to review the outstanding accounts receivable monthly, as well as the bad debt write-offs experienced in the past, and establish an allowance for doubtful accounts. Account balances are charged off against the allowance when management determines it is probable the receivable will not be recovered.
Financing Receivables, Policy	Each subsidiary leases its respective transmission assets to a single counterparty. Both counterparties are considered credit worthy and are expected to pay their obligations when due, thus, no allowance for credit loss has been recognized. Management bases this assessment on the following common factors of each counterparty: • both counterparties use the respective transmission facilities to move electricity from its power plants to the regional transmission grid, • neither counterparty has another avenue to move electricity from its respective power plants to the regional transmission grid, • the stream of payments was approved by FERC through respective rate orders, and • both counterparties serve retail and wholesale customers in their respective service territories under LPSC oversight that allows recovery of prudent costs, of which, the stream of payments under the direct financing leases appear to be prudent. Management monitors both entities for indication of adverse actions by their respective public service commissions and market conditions which would indicate an inability to pay their obligations under the direct financing leases when due.
Reserves, Policy	Cleco maintains property insurance on generating stations, buildings and contents, and substations. Cleco is self-insured for any damage to transmission and distribution lines. To mitigate the exposure to potential financial loss for damage to lines, Cleco maintains an LPSC-approved funded storm reserve. Cleco Power also maintains liability and workers’ compensation insurance to mitigate financial losses due to injuries and damages to the property of others. Cleco’s insurance covers claims that exceed certain self-insured limits. For claims that do not meet the limits to be covered by insurance, Cleco Power maintains reserves. Additionally, Cleco maintains directors and officers insurance to protect managers from claims which may arise from their decisions and actions taken within the scope of their regular duties.
Cash Equivalents, Policy	Cleco considers highly liquid, marketable securities, and other similar instruments with original maturity dates of three months or less to be cash equivalents.
Restricted Cash, Policy	Cleco Katrina/Rita has the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash is collected, it is restricted for payment of administration fees, interest, and principal on storm recovery bonds. Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general company purposes.
Equity Investments, Policy	Cleco and Cleco Power account for investments in unconsolidated affiliated companies using the equity method of accounting. The amounts reported on Cleco and Cleco Power’s Consolidated Balance Sheets represent assets contributed by Cleco or Cleco Power, plus their share of the net income of the affiliate, less any distributions of earnings (dividends) received from the affiliate. The revenues and expenses (excluding income taxes) of these affiliates are netted and reported on one line item as equity income from investees on Cleco and Cleco Power’s Consolidated Statements of Income. Cleco evaluates for impairments of equity method investments at each balance sheet date to determine if events and circumstances have occurred that indicate a possible other-than-temporary decline in the fair value of the investment and the possible inability to recover the carrying value through operations. Cleco uses estimates of the future cash flows from the investee and observable market transactions in order to calculate fair value and recoverability. An impairment is recognized when an other-than-temporary decline in market value occurs and recovery of the carrying value is not probable. 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 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 Consolidated Statements of Income
Regulatory Income Taxes, Policy	Cleco accounts for income taxes under the asset and liability method. Cleco provides for federal and state income taxes currently payable, as well as for those deferred due to timing differences between reporting income and expenses for financial statement purposes versus tax purposes. Deferred tax assets and liabilities are recognized for the future tax consequences attributable to temporary differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax basis. Deferred tax assets and liabilities are measured using enacted income tax rates expected to be applied to taxable income in the years in which those temporary differences are expected to be recovered or settled. Deferred tax assets and liabilities are classified as non-current on Cleco and Cleco Power’s Consolidated Balance Sheets. Cleco’s income tax expense and related regulatory assets and liabilities could be affected by changes in its assumptions and estimates and by ultimate resolution of assumptions and estimates with taxing authorities. Cleco files a federal income tax return for all wholly owned subsidiaries. Cleco Power computes its federal and state income taxes as if it were a stand-alone taxpayer. The LPSC generally requires Cleco Power to flow the effects of state income taxes to customers immediately. The LPSC specifically requires that the state tax benefits associated with the deductions related to certain storm damages be normalized. The regulatory asset recorded for deferred income taxes represents the effect of tax benefits or detriments that must be flowed through to customers as they are received or paid. The amounts deferred are attributable to differences between book and tax recovery periods.
Income Taxes, Policy	The gross investment amortization expense of the NMTC Fund will be recognized over a over a ten -year period, with two years remaining under the new amendment, using the cost method. The grants received under Section 1603, which allow certain projects to receive a federal grant in lieu of tax credits, and other cash reduce the basis of the investment. Periodic amortization of the investment and the deferred taxes generated by the basis reduction temporary difference are included as components of income tax expense. Investment tax credits, which were deferred for financial statement purposes, are amortized as a reduction to income tax expense over the estimated service lives of the properties that gave rise to the credits. Cleco and the NMTC Fund have elected to receive cash grants under the ARRA for investments in various projects. Cleco has elected to reduce the carrying value of the qualifying assets as cash grants are received, which will reduce the amount of depreciation expense recognized after the underlying assets are placed in service. Certain cash grants also reduce the tax basis of the underlying assets. Grants received via the NMTC Fund reduce the carrying value of the investment for GAAP, but do not reduce the income tax basis of the investment. Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a tax benefit will not be realized. Cleco classifies income tax penalties as a component of other expenses. Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense.
Debt Issuance Costs, Premiums, and Discounts, Policy	Issuance costs, premiums, and discounts applicable to debt securities are amortized to interest expense ratably over the lives of the related issuances. Expenses and call premiums related to refinanced Cleco Power debt are deferred and amortized over the life of the new issuance. Debt issuance costs, premiums, and discounts are presented as a direct deduction from the carrying value of the related debt liability.
Revenue and Fuel Costs, Policy	Utility Revenue Revenue from sales of electricity is recognized when the service is provided. The costs of fuel and purchased power used for retail customers currently are recovered from customers through the FAC. These costs are subject to audit and final determination by regulators. Excise taxes and pass-through fees collected on the sale of electricity are not recorded in utility revenue. Unbilled Revenue Cleco Power accrues estimated revenue monthly for energy used by customers but not yet billed. The monthly estimated unbilled revenue amounts are recorded as unbilled revenue and a receivable. During the third quarter of 2014, Cleco Power began using actual customer energy consumption data available from AMI to calculate unbilled revenues. Other Operations Revenue Other operations revenue is recognized at the time products or services are provided to and accepted by customers, and collectability is reasonably assured. Sales/Excise Taxes Cleco Power collects a sales and use tax on the sale of electricity that subsequently is remitted to the state in accordance with state law. These amounts are not recorded as income or expense on Cleco’s Consolidated Statements of Income but are reflected at gross amounts on Cleco’s Consolidated Balance Sheets as a receivable until the tax is collected and as a payable until the liability is paid. Cleco currently does not have any excise taxes reflected on its income statement. Franchise Fees Cleco Power collects a consumer fee for one of its franchise agreements. This fee is not recorded on Cleco’s Consolidated Statements of Income as revenue and expense, but is reflected at gross amounts on Cleco’s Consolidated Balance Sheets as a receivable until it is collected and as a payable until the liability is paid.
Allowance for Funds Used During Construction (AFUDC), Policy	The capitalization of AFUDC by Cleco Power is a utility accounting practice prescribed by FERC and the LPSC. AFUDC represents the estimated debt and equity costs of capital funds that are necessary to finance construction of new and existing facilities. While cash is not realized currently from such allowance, AFUDC increases the revenue requirement over the same life of the plant through a higher rate base and higher depreciation. Under regulatory practices, a return on and recovery of AFUDC is permitted in setting rates charged for utility services.
Fair Value Measurement, 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.
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 Consolidated Balance Sheets. Realized gains or losses on settled FTRs are recorded in Fuel used for electric generation on Cleco Power’s 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 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 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 in the second half of 2017.
Accounting for MISO Transactions, Policy	Cleco Power participates in MISO’s Energy and Operating Reserve market where sales and purchases are netted hourly. If the hourly activity nets to sales, the result is reported in Electric operations on Cleco and Cleco Power’s Consolidated Statements of Income. If the hourly activity nets to purchases, the result is reported in Power purchased for utility customers on Cleco and Cleco Power’s Consolidated Statements of Income.
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. Earlier application is permitted only as of annual reporting periods beginning after December 15, 2016, including interim reporting periods within that reporting period. Cleco does not plan to early adopt the amended guidance. 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 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), accounting for contributions in aid of construction, 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 August 2014, FASB amended the guidance for the presentation and disclosure of uncertainties about an entity’s ability to continue as a going concern. The amended guidance requires management to evaluate whether there is substantial doubt about its ability to continue as a going concern. The guidance provides that management should consider relevant conditions or events that are known or reasonably known on the date the financial statements are issued. If substantial doubt exists, then the principle events giving rise to the substantial doubt and management’s plans to alleviate those doubts should be disclosed. The adoption of this guidance is effective for annual reporting periods ending after December 15, 2016, and for interim periods thereafter. Management’s evaluation of Cleco’s ability to continue as a going concern concluded that substantial doubt does not exist. The adoption of this guidance will not have an impact on the results of operations, financial condition, or cash flows of the Registrants. In September 2015, FASB amended the business combinations guidance to simplify the accounting for measurement-period adjustments. This guidance eliminates the requirement to retrospectively account for these adjustments. The adoption of this guidance is effective for fiscal years beginning after December 15, 2015, including interim periods within those fiscal years. This amendment should be applied prospectively to adjustments to provisional amounts that occur after the effective date with earlier application permitted. Cleco was subject to this guidance starting January 1, 2016. As a result of the Merger on April 13, 2016, Cleco adopted this guidance and does not expect it to have a material impact on the results of operations, financial condition, or cash flows of the Registrants as a result of provisional merger adjustments in future periods. In January 2016, FASB amended the guidance for recognition and measurement of financial assets and liabilities. These amendments address certain aspects of recognition, measurement, presentation, and disclosure of financial instruments. The adoption of this guidance is effective for fiscal years beginning after December 15, 2017, including interim periods within those years. Early adoption of certain provisions of this guidance is permitted as of the beginning of the fiscal year of adoption. Entities should apply these amendments by means of a cumulative-effect adjustment to the balance sheet as of the beginning of the fiscal year of adoption. The amendments related to equity securities without readily determinable fair value should be applied prospectively to equity investments that exist as of the date of adoption. Management does not expect this guidance to have a significant impact on the results of operations, financial condition, or cash flows of the Registrants. In 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 March 2016, FASB amended the derivatives and hedging accounting guidance to address the effect of derivative contract novations on existing hedge accounting relationships. The amended guidance clarifies that a change in the counterparty to a derivative instrument that has been designated as the hedging instrument does not, in and of itself, require dedesignation of the hedging relationship provided that all other hedge accounting criteria continue to be met. The adoption of this guidance is effective for fiscal years beginning after December 15, 2016, including interim periods within those years. Entities have the option to apply these amendments on either a prospective basis or a modified retrospective basis. This guidance will not have an impact on the results of operations, financial condition, or cash flows of the Registrants. In March 2016, FASB amended the derivatives and hedging accounting guidance related to contingent put and call options in debt instruments. This guidance clarifies the requirements for assessing whether contingent put and call options that can accelerate the payment of principal on debt instruments are clearly and closely related to their debt hosts. Entities performing the assessment will be required to assess the embedded put and call options solely in accordance with the four-step decision sequence clarified in the amended guidance. The adoption of this guidance is effective for fiscal years beginning after December 15, 2016, including interim periods within those years. Entities should apply these amendments on a modified retrospective basis to existing debt instruments as of the beginning of the fiscal year for which the amendments are effective. 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 2016, FASB amended the accounting guidance to simplify the transition to the equity method of accounting. This guidance impacts entities that have an investment that becomes qualified for the equity method of accounting as a result of an increase in the level of ownership interest or degree of influence. This amended guidance eliminates the requirement to retroactively adopt the equity method of accounting. The adoption of this guidance is effective for fiscal years beginning after December 15, 2016, including interim periods within those years. Early adoption is permitted. These amendments should be applied prospectively upon their effective date to increases in the level of ownership interest or degree of influence that results in the adoption of the equity method. Management does not expect this guidance to have any impact on the results of operations, financial condition, or cash flows of the Registrants. In June 2016, FASB amended the guidance for the measurement of credit losses on financial instruments. The guidance affects entities holding financial assets and net investment in leases that are not accounted for at fair value through net income. The guidance affects loans, debt securities, trade receivables, net investments in leases, off-balance-sheet credit exposures, reinsurance receivables, and any other financial assets not excluded from the scope that have the contractual right to receive cash. The adoption of this guidance is effective for fiscal years beginning after December 15, 2019, including interim periods within those years. Early adoption is permitted. Management does not expect this guidance to have any impact on the results of operations, financial condition, or cash flows of the Registrants. In August 2016, FASB amended the guidance for certain cash flow issues with the objective of reducing existing diversity in practice. This guidance affects the cash flow classification related to certain types of transactions including debt, contingent consideration, proceeds from the settlement of insurance claims, and distributions from equity method investees. The adoption of this guidance is effective for fiscal years beginning after December 15, 2017, including interim periods within those years. 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 October 2016, FASB amended the income tax guidance related to intra-entity transfers of assets other than inventory. Current GAAP prohibits the recognition of current and deferred income taxes for an intra-entity asset transfer until the asset has been sold to an outside party. This new guidance states that an entity should recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs. The adoption of this guidance is effective for annual reporting periods beginning after December 15, 2017, including interim reporting periods within those annual reporting periods. Early adoption is permitted for all entities as of the beginning of an annual reporting period for which financial statements have not been issued or made available for issuance. Management is evaluating the impact that the adoption of this guidance will have on the result of operations, financial condition, or cash flows of the Registrants. In October 2016, FASB amended the consolidations guidance as it relates to interest held through related parties that are under common control. This amended guidance changes the evaluation of whether a reporting entity is the primary beneficiary of a variable interest entity (VIE) by changing how a reporting entity that is a single decision maker of a VIE treats indirect interests in the entity held through related parties that are under common control with the reporting entity. The adoption of this guidance is effective for fiscal years beginning after December 15, 2016, including interim periods within those fiscal years. Early adoption is permitted. The adoption of this guidance is not expected to have an effect 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, 2016, including interim reporting periods within those fiscal years. Early adoption is permitted. Management is currently 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 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 loss will instead be measured at the amount by which a reporting unit’s carrying amount exceeds its fair value. 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.
Business Combinations, Policy	Most of the carrying values of Cleco’s assets 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. A fair value adjustment was made to record the stepped-up basis for the Coughlin assets, since Cleco Power is able to earn a return on and recover these costs from customers. At the date of the Merger, the gross balance of fixed depreciable assets at Cleco was adjusted to be net of accumulated depreciation, as no accumulated depreciation existed on the date of the Merger. Since pushdown accounting was not elected at the Cleco Power level, Cleco Power retained its accumulated depreciation. 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 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 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 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 Consolidated Balance Sheet to reflect the valuation of the Cleco trade name. This adjustment is included in Intangible assets on Cleco’s 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 Consolidated Statement of Income. On the date of the Merger, fair value adjustments were recorded on Cleco’s 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 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 will be amortized over the remaining term of the applicable contract. The amortization of the power supply agreements is included in Electric operations on Cleco’s Consolidated Statement of Income. The net increase in deferred tax liabilities on Cleco’s 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. For more information, see Note 4 — “Regulatory Assets and Liabilities.” 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. Accounting guidance provides that the allocation of the purchase price may be modified up to one year from the date of the Merger, as more information is obtained about the fair value of assets acquired and liabilities assumed. The preliminary amounts recognized are subject to revision until the valuations are completed and to the extent that additional information is obtained about the facts and circumstances that existed as of the date of the Merger. Except for the effects of the positions related to the Merger reflected on income tax returns, Cleco completed its evaluation and determination of the fair value of certain assets and liabilities acquired as of December 31, 2016. While management believes the positions reflected on the income tax returns are reasonable, the returns have not been audited by the applicable taxing authorities. At the date of the Merger, the gross balance of the Cleco Katrina/Rita intangible asset for Cleco was adjusted to be net of accumulated amortization, as no accumulated amortization existed on the date of the Merger.
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
Regulatory Assets and Liabilities, ARO, Policy	Cleco Power has recorded an ARO liability for the retirement of certain ash disposal facilities.
Share-based Compensation, Option, and Incentive Plans, Policy	Cleco did not modify any of the terms of outstanding awards. Cleco recognized stock-based compensation expense for these provisions in accordance with the non-substantive vesting period approach. Recipients of non-vested stock had full voting rights of a stockholder. At the time restrictions lapsed, the accrued dividend equivalent units were paid to the recipient only to the extent that target shares vested. In order to vest, the non-vested stock required the satisfaction of a service requirement and a market-based requirement. Recipients of non-vested stock were eligible to receive opportunity instruments if certain market-based measures were exceeded. Cleco also awarded non-vested stock with only a service period requirement to certain employees and directors. These awards required the satisfaction of a predetermined service period in order for the shares to vest. 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. Prior to the completion of the Merger, stock options, restricted stock, also known as non-vested stock, common stock equivalent units, and stock appreciation rights were available to be granted or awarded to certain officers, key employees, or directors of Cleco Corporation and its affiliates under the LTIP. On December 31, 2009, the 2000 LTIP expired and no further grants or awards were made under this plan. During 2015, all restrictions on non-vested shares previously awarded pursuant to the 2000 LTIP had lapsed. With shareholder approval, the 2010 LTIP became effective January 1, 2010. Under this plan, a maximum of 2,250,000 shares of Cleco Corporation’s common stock was available to be granted or awarded. During 2015, Cleco granted 9,611 shares of stock to directors of Cleco pursuant to the LTIP. All of these shares vested immediately upon award and were issued from shares previously purchased through Cleco’s common stock repurchase program. As stated above, the LTIP plan was terminated upon completion of the Merger. Prior to October 17, 2014, regular, full-time, and part-time employees of Cleco Corporation and its participating subsidiaries, except officers, general managers, and employees who owned 5% or more of Cleco Corporation’s stock, were eligible to participate in the ESPP. No trust or other fiduciary account was established in connection with the ESPP. Shares of common stock were purchased at a 5% discount of the fair market value as of the last trading day of each calendar quarter. A participant could purchase a maximum of 125 shares per offering period. Dividends received on shares were automatically reinvested as required by the dividend reinvestment plan (DRIP) provisions of the ESPP. A maximum of 73,400 shares of common stock was available to be purchased under the ESPP, subject to adjustment for changes in the capitalization of Cleco Corporation. The Compensation Committee of Cleco Corporation’s Board of Directors monitored the ESPP. The Compensation Committee and the Board of Directors possessed the authority to amend the ESPP, but shareholder approval was required for any amendment that increased the number of shares covered by the ESPP. As stated above, the ESPP plan was terminated upon completion of the Merger. The ESPP did not contain optionality features beyond those listed by the authoritative guidance on stock-based compensation. Therefore, Cleco was not required to recognize a fair-value expense related to the ESPP.
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. 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 will have their annual bonuses set at target rather than actual awards for years 2016 and 2017 for the average incentive award portion of their SERP benefit calculation. 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. 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 from which the officer retired. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator. Cleco’s 401(k) Plan is intended to provide active, eligible employees with voluntary, long-term savings and investment opportunities. The 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 Plan, employer contributions can be in the form of cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Participation in the Plan is voluntary and active Cleco employees are eligible to participate. 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.
Segment Reporting, Policy	The financial results of Cleco’s segment is presented on an accrual basis.
Consolidation, 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.

Summary of Significant Accoun33

Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Line Items]
Amortization of Computer Software	Amortization of capitalized computer software costs charged to expense in Cleco and Cleco Power’s Statements of Income for the years ending December 31, 2016 , 2015 , and 2014 is shown in the following tables: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE Amortization $ 2,351 $ 921 $ 2,194 $ 1,397
Property, Plant, and Equipment	At December 31, 2016 , and 2015 , Cleco and Cleco Power’s property, plant, and equipment consisted of the following: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Utility plants Production $ 1,866,601 $ 2,385,345 Distribution 955,126 1,350,475 Transmission 503,996 665,338 Other utility plant 146,976 244,540 Other property, plant, and equipment 3,882 15,514 Total property, plant, and equipment 3,476,581 4,661,212 Accumulated depreciation (75,816 ) (1,536,158 ) Net property, plant, and equipment $ 3,400,765 $ 3,125,054 Depreciation on property, plant, and equipment is calculated primarily on a straight-line basis over the useful lives of the assets, as follows: CATEGORY YEARS Utility Plants Production 10 – 95 Distribution 15 – 50 Transmission 5 – 55 Other utility plant 5 – 45 Other property, plant, and equipment 5 – 45
Schedule of Acquisition Adjustments, Less Accumulated Depreciation	The plant acquisition adjustments and accumulated amortization reported in property, plant, and equipment and accumulated depreciation on Cleco and Cleco Power’s Consolidated Balance Sheets at December 31, 2016 , and 2015 are shown in the following tables: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Acadia Unit 1 Plant acquisition adjustment $ 76,116 $ 95,578 Accumulated amortization (2,287 ) (18,567 ) Net plant acquisition adjustment $ 73,829 $ 77,011 Teche and other Plant acquisition adjustment $ 544 $ 5,271 Accumulated amortization (183 ) (4,655 ) Net plant acquisition adjustment $ 361 $ 616
Restricted Cash	Cleco and Cleco Power’s restricted cash and cash equivalents consisted of: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current Cleco Katrina/Rita’s storm recovery bonds $ 9,213 $ 9,263 Cleco Power’s charitable contributions 1,200 — Cleco Power’s rate credit escrow 12,671 — Total current 23,084 9,263 Non-current Diversified Lands’ mitigation escrow 21 21 Cleco Power’s future storm restoration costs 17,379 16,174 Cleco Power’s charitable contributions 4,179 — Cleco Power’s rate credit escrow 1,831 — Total non-current 23,410 16,195 Total restricted cash and cash equivalents $ 46,494 $ 25,458
Cleco Power [Member]
Accounting Policies [Line Items]
Amortization of Computer Software	Cleco Power FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Amortization $ 2,405 $ 1,718 $ 1,096
Property, Plant, and Equipment	Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Regulated utility plants Production $ 2,406,572 2,385,345 Distribution 1,405,703 1,350,475 Transmission 719,052 665,338 Other utility plant 259,238 244,540 Total property, plant, and equipment 4,790,565 4,645,698 Accumulated depreciation (1,618,241 ) (1,525,298 ) Net property, plant, and equipment $ 3,172,324 $ 3,120,400
Schedule of Acquisition Adjustments, Less Accumulated Depreciation	Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Acadia Unit 1 Plant acquisition adjustment $ 95,578 $ 95,578 Accumulated amortization (21,749 ) (18,567 ) Net plant acquisition adjustment $ 73,829 $ 77,011 Teche and other Plant acquisition adjustment $ 5,271 $ 5,271 Accumulated amortization (4,910 ) (4,655 ) Net plant acquisition adjustment $ 361 $ 616
Restricted Cash	Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current Cleco Katrina/Rita’s storm recovery bonds $ 9,213 $ 9,263 Charitable contributions 1,200 — Rate credit escrow 12,671 — Total current 23,084 9,263 Non-current Future storm restoration costs 17,379 16,174 Charitable contributions 4,179 — Rate credit escrow 1,831 — Total non-current 23,389 16,174 Total restricted cash and cash equivalents $ 46,473 $ 25,437

Business Combinations (Tables)

Business Combinations (Tables)	12 Months Ended
	Dec. 31, 2016
Business Combinations [Abstract]
Schedule of Business Acquisitions, by Acquisition [Table Text Block]	Pushdown accounting was applied to Cleco, and accordingly, the Cleco consolidated assets acquired and liabilities assumed were recorded on April 13, 2016, at their fair values as follows: Purchase Price Allocation (THOUSANDS) AT APR. 13, 2016 Current assets $ 455,016 Property, plant, and equipment, net 3,432,144 Goodwill 1,490,797 Other long-term assets 1,023,487 Less Current liabilities 228,515 Net deferred income tax liabilities 1,059,939 Other deferred credits 279,379 Long-term debt, net 1,470,126 Total purchase price $ 3,363,485 The following tables present 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

Regulatory Assets and Liabili35

Regulatory Assets and Liabilities (Tables)	12 Months Ended
	Dec. 31, 2016
Regulatory Assets and Liabilities [Line Items]
Schedule of Regulatory Assets [Table Text Block]	The following table summarizes Cleco’s net regulatory assets and liabilities: Cleco SUCCESSOR (1) PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Total Cleco Power regulatory assets, net $ 543,973 $ 548,345 Cleco Holdings’ Merger adjustments Fair value of long-term debt 155,776 — Postretirement costs 23,362 — Financing costs 8,966 — Debt issuance costs 7,606 — Total Cleco regulatory assets, net $ 739,683 $ 548,345 (1) Cleco Holdings’ regulatory assets include acquisition accounting adjustments as a result of the Merger.
Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Schedule of Regulatory Assets [Table Text Block]	The following table summarizes Cleco Power’s net regulatory assets and liabilities: Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 REMAINING RECOVERY PERIOD Total federal regulatory (liability) asset — income taxes $ (635 ) $ 5,614 Total state regulatory asset — income taxes 112,751 105,868 AFUDC 126,335 127,092 Total investment tax credit (1,002 ) (1,633 ) Total regulatory assets — deferred taxes, net 237,449 236,941 * Mining costs 6,372 8,921 2.5 yrs. Interest costs 4,860 5,221 * AROs (1) 2,096 2,462 * Postretirement costs (1) 145,268 150,274 * Tree trimming costs 5,549 6,318 * Training costs 6,708 6,863 43 yrs. Surcredits, net (2) 5,876 9,661 * Amended lignite mining agreement contingency (1) — 3,781 — AMI deferred revenue requirement 4,772 5,318 9 yrs. Production operations and maintenance expenses 13,999 12,436 * AFUDC equity gross-up (2) 70,423 71,444 * Acadia Unit 1 acquisition costs 2,442 2,548 23 yrs. Financing costs 8,663 9,032 * Biomass costs 18 50 0.5 yrs. MISO integration costs 1,404 2,340 1.5 yrs. Coughlin transaction costs 999 1,030 32.5 yrs. Corporate franchise tax 1,308 373 * Acadia FRP true-up — 377 — MATS Costs 4,270 — 1.5 yrs Other 710 357 * Total regulatory assets 285,737 298,806 PPA true-up — (312 ) — Fuel and purchased power 20,787 12,910 * Total regulatory assets, net $ 543,973 $ 548,345 (1) Represents regulatory assets in which cash has not yet been expended and the assets are offset by liabilities that do not incur a carrying cost. (2) Represents regulatory assets for past expenditures that were not earning a return on investment at December 31, 2016. All other assets are earning a return on investment. * For information related to the remaining recovery periods, refer to the following disclosures for each specific regulatory asset.

Jointly Owned Generation Units

Jointly Owned Generation Units (Tables)	12 Months Ended
	Dec. 31, 2016
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Generation Units	At December 31, 2016 , the investment in and accumulated depreciation for each generating unit on Cleco and Cleco Power’s Consolidated Balance Sheets were as follows: Cleco SUCCESSOR AT DEC. 31, 2016 (THOUSANDS, EXCEPT PERCENTAGES AND MW) RODEMACHER UNIT 2 DOLET HILLS TOTAL Utility plant in service $ 70,136 $ 177,201 $ 247,337 Accumulated depreciation $ 1,530 $ 5,783 $ 7,313 Construction work in progress $ 166 $ 3,193 $ 3,359 Ownership interest percentage 30 % 50 % Nameplate capacity (MW) 523 650 Ownership interest (MW) 157 325
Cleco Power [Member]
Jointly Owned Utility Plant Interests [Line Items]
Jointly Owned Generation Units	Cleco Power AT DEC. 31, 2016 (THOUSANDS, EXCEPT PERCENTAGES AND MW) RODEMACHER UNIT 2 DOLET HILLS TOTAL Utility plant in service $ 144,316 $ 394,698 $ 539,014 Accumulated depreciation $ 75,710 $ 223,280 $ 298,990 Construction work in progress $ 166 $ 3,193 $ 3,359 Ownership interest percentage 30 % 50 % Nameplate capacity (MW) 523 650 Ownership interest (MW) 157 325

Fair Value Accounting (Tables)

Fair Value Accounting (Tables)	12 Months Ended
	Dec. 31, 2016
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 in Cleco and Cleco Power’s Consolidated Balance Sheets: Cleco SUCCESSOR PREDECESSOR AT DEC. 31, 2016 AT DEC. 31, 2015 (THOUSANDS) CARRYING VALUE* ESTIMATED FAIR VALUE CARRYING VALUE* ESTIMATED FAIR VALUE Long-term debt $ 2,768,149 $ 2,754,518 $ 1,299,529 $ 1,463,989 * The carrying value of long-term debt does not include deferred issuance costs of $11.7 million in 2016 and $9.9 million in 2015.
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 or disclosed on a recurring basis: Cleco CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING: SUCCESSOR PREDECESSOR (THOUSANDS) 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) AT DEC. 31, 2015 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 $ 66,410 $ — $ 66,410 $ — $ 89,584 $ — $ 89,584 $ — FTRs 7,884 — — 7,884 7,673 — — 7,673 Total assets $ 74,294 $ — $ 66,410 $ 7,884 $ 97,257 $ — $ 89,584 $ 7,673 Liability Description Long-term debt $ 2,754,518 $ — $ 2,754,518 $ — $ 1,463,989 $ — $ 1,463,989 $ — FTRs 201 — — 201 275 — — 275 Total liabilities $ 2,754,719 $ — $ 2,754,518 $ 201 $ 1,464,264 $ — $ 1,463,989 $ 275
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: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE Beginning balance $ 3,458 $ 7,398 $ 9,949 Unrealized gains (losses)* 3,119 (1,031 ) (1,476 ) Purchases 12,896 2,070 20,319 Settlements (11,790 ) (4,979 ) (21,394 ) Ending balance $ 7,683 $ 3,458 $ 7,398 * Unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco and Cleco Power's Consolidated Balance Sheets.
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 December 31, 2016 : Cleco FAIR VALUE VALUATION TECHNIQUE SIGNIFICANT UNOBSERVABLE INPUTS FORWARD PRICE RANGE (THOUSANDS, EXCEPT DOLLAR PER MWh) Assets Liabilities Low High SUCCESSOR FTRs at December 31, 2016 $ 7,884 $ 201 RTO auction pricing FTR price - per MWh $ (3.61 ) $ 6.04 PREDECESSOR FTRs at December 31, 2015 $ 7,673 $ 275 RTO auction pricing FTR price - per MWh $ (3.63 ) $ 4.51
Cleco Power [Member]
Fair Value [Line Items]
Fair Value By Balance Sheet Grouping	Cleco Power AT DEC. 31, 2016 AT DEC. 31, 2015 (THOUSANDS) CARRYING VALUE* ESTIMATED FAIR VALUE CARRYING VALUE* ESTIMATED FAIR VALUE Long-term debt $ 1,262,373 $ 1,418,693 $ 1,265,529 $ 1,429,989 * The carrying value of long-term debt does not include deferred issuance costs of $9.4 million in 2016 and $9.6 million in 2015.
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 DEC. 31, 2016 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) AT DEC. 31, 2015 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 $ 65,089 $ — $ 65,089 $ — $ 87,363 $ — $ 87,363 $ — FTRs 7,884 — — 7,884 7,673 — — 7,673 Total assets $ 72,973 $ — $ 65,089 $ 7,884 $ 95,036 $ — $ 87,363 $ 7,673 Liability Description Long-term debt $ 1,418,693 $ — $ 1,418,693 $ — $ 1,429,989 $ — $ 1,429,989 $ — FTRs 201 — — 201 275 — — 275 Total liabilities $ 1,418,894 $ — $ 1,418,693 $ 201 $ 1,430,264 $ — $ 1,429,989 $ 275
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Table Text Block]	Cleco Power FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 Beginning balance $ 7,398 $ 9,949 Unrealized gains (losses)* 2,088 (1,476 ) Purchases 14,966 20,319 Settlements (16,769 ) (21,394 ) Ending balance $ 7,683 $ 7,398 * Unrealized gains (losses) are reported through Accumulated deferred fuel on Cleco and Cleco Power's Consolidated Balance Sheets.
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Table Text Block]	Cleco Power FAIR VALUE VALUATION TECHNIQUE SIGNIFICANT UNOBSERVABLE INPUTS FORWARD PRICE RANGE (THOUSANDS, EXCEPT DOLLAR PER MWh) Assets Liabilities Low High FTRs at December 31, 2016 $ 7,884 $ 201 RTO auction pricing FTR price - per MWh $ (3.61 ) $ 6.04 FTRs at December 31, 2015 $ 7,673 $ 275 RTO auction pricing FTR price - per MWh $ (3.63 ) $ 4.51
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 Consolidated Balance Sheets at December 31, 2016 , and 2015 : Cleco DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS SUCCESSOR PREDECESSOR (THOUSANDS) BALANCE SHEET LINE ITEM AT DEC. 31, 2016 AT DEC. 31, 2015 Commodity-related contracts FTRs: Current Energy risk management assets $ 7,884 $ 7,673 Current Energy risk management liabilities 201 275 Commodity-related contracts, net $ 7,683 $ 7,398
Effect of Derivatives On Consolidated Statements of Income	The following table presents the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Consolidated Statements of Income for the years December 31, 2016 , 2015 , and 2014 : Cleco AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES SUCCESSOR PREDECESSOR (THOUSANDS) DERIVATIVES LINE ITEM APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE Commodity contracts FTRs (1) Electric operations $ 30,915 $ 8,563 50,594 $ 74,454 FTRs (1) Power purchased for utility customers (14,941 ) (5,761 ) (27,509 ) (46,386 ) Total $ 15,974 $ 2,802 $ 23,085 $ 28,068 (1) For the periods January 1, 2016 - April 12, 2016, and April 13, 2016 - December 31, 2016, unrealized (losses) gains associated with FTRs of $(1.0) million and $3.1 million , respectively, were reported through Accumulated deferred fuel on the balance sheet. For the years ended December 31, 2015, and 2014, unrealized losses associated with FTRs of $1.5 million and $2.7 million , respectively, were reported through Accumulated deferred fuel on the balance sheet. Cleco Power AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES FOR THE YEAR ENDED DEC. 31, (THOUSANDS) DERIVATIVES LINE ITEM 2016 2015 2014 Commodity contracts FTRs (1) Electric operations $ 39,478 $ 50,594 $ 74,454 FTRs (1) Power purchased for utility customers (20,702 ) (27,509 ) (46,386 ) Total $ 18,776 $ 23,085 $ 28,068
Derivatives Not Designated as Hedging Instrument [Member] | Cleco Power [Member]
Fair Value [Line Items]
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value [Table Text Block]	Cleco Power DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS (THOUSANDS) BALANCE SHEET LINE ITEM AT DEC. 31, 2016 AT DEC. 31, 2015 Commodity-related contracts FTRs: Current Energy risk management assets $ 7,884 $ 7,673 Current Energy risk management liabilities 201 275 Commodity-related contracts, net $ 7,683 $ 7,398
Effect of Derivatives On Consolidated Statements of Income	Cleco Power AMOUNT OF GAIN/(LOSS) RECOGNIZED IN INCOME ON DERIVATIVES FOR THE YEAR ENDED DEC. 31, (THOUSANDS) DERIVATIVES LINE ITEM 2016 2015 2014 Commodity contracts FTRs (1) Electric operations $ 39,478 $ 50,594 $ 74,454 FTRs (1) Power purchased for utility customers (20,702 ) (27,509 ) (46,386 ) Total $ 18,776 $ 23,085 $ 28,068 (1) For the years ended December 31, 2016, 2015, and 2014, unrealized gains (losses) associated with FTRs of $2.1 million , $(1.5) million , and $(2.7) million , respectively, were reported through Accumulated deferred fuel on the balance sheet.

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt Instrument [Line Items]
Total Indebtedness	Cleco’s total indebtedness as of December 31, 2016 , and 2015 was as follows: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Total Cleco Power long-term debt, net $ 1,235,056 $ 1,234,039 Senior notes, 3.250%, due 2023 165,000 — Senior notes, 3.743%, due 2026 535,000 — Senior notes, 4.973%, due 2046 350,000 — Bank term loan, variable rate, due 2021 300,000 — Credit facility draws — 34,000 Unamortized debt issuance costs (2,261 ) (336 ) Fair value adjustment 155,776 — Total long-term debt, net $ 2,738,571 $ 1,267,703
Future Amounts Payable Under Long-Term Debt Agreements	The principal amounts payable under long-term debt agreements for each year through 2021 and thereafter are as follows: (THOUSANDS) CLECO CLECO POWER Amounts payable under long-term debt arrangements For the year ending Dec. 31, 2017 $ 17,896 $ 17,896 2018 $ 19,193 $ 19,193 2019 $ 20,571 $ 20,571 2020 $ 11,055 $ 11,055 2021 $ 300,000 $ — Thereafter $ 2,250,000 $ 1,200,000
Cleco Power [Member]
Debt Instrument [Line Items]
Total Indebtedness	Cleco Power’s total indebtedness as of December 31, 2016 , and 2015 was as follows: Cleco Power AT DEC. 31, (THOUSANDS) 2016 2015 Bonds Senior notes, 6.65%, due 2018 $ — $ 250,000 Senior notes, 3.68%, due 2025 75,000 75,000 Senior notes, 3.47%, due 2026 130,000 — Senior notes, 4.33%, due 2027 50,000 50,000 Senior notes, 3.57%, due 2028 200,000 — Senior notes, 6.50%, due 2035 295,000 295,000 Senior notes, 6.00%, due 2040 250,000 250,000 Senior notes, 5.12%, due 2041 100,000 100,000 Series A GO Zone bonds, 2.00%, due 2038, mandatory tender in 2020 50,000 50,000 Series B GO Zone bonds, 4.25%, due 2038 50,000 50,000 Solid waste disposal facility bonds, 4.70%, due 2036, callable November 1, 2016 — 60,000 Cleco Katrina/Rita’s storm recovery bonds, 4.41%, due 2020 1,115 17,929 Cleco Katrina/Rita’s storm recovery bonds, 5.61%, due 2023 67,600 67,600 Total bonds 1,268,715 1,265,529 Other long-term debt Barge lease obligations, ending 2017 1,819 4,425 Gross amount of long-term debt 1,270,534 1,269,954 Less: long-term debt due within one year 17,896 16,814 Less: lease obligations classified as long-term debt due within one year 1,819 2,607 Unamortized debt discount (6,342 ) (6,885 ) Unamortized debt issuance costs (9,421 ) (9,609 ) Total long-term debt, net $ 1,235,056 $ 1,234,039

Common Stock (Tables)

Common Stock (Tables)	12 Months Ended
	Dec. 31, 2016
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Summary of Non-Vested Stock Activity	A summary of non-vested stock activity during 2016 is presented in the following table: PREDECESSOR SHARES WEIGHTED-AVERAGE GRANT-DATE FAIR VALUE Non-vested at Jan. 1, 2016 269,988 $ 48.11 Vested (217,588 ) $ 46.53 Forfeited (52,400 ) $ 54.64 Non-vested at Apr. 12, 2016 — $ —
Fair Value Assumptions of Non-Vested Stock	The fair value of shares of non-vested stock granted during 2015 and 2014 under the LTIP was estimated on the date of grant and the expense was calculated using the Monte Carlo simulation model with the assumptions listed in the following table: PREDECESSOR FOR THE YEAR ENDED DEC. 31, 2015 FOR THE YEAR ENDED DEC. 31, 2014 Expected term (in years) (1) 3.0 3.0 Volatility of Cleco stock (2) 15.8 % 17.3 % Correlation between Cleco stock volatility and peer group 63.1 % 66.5 % Expected dividend yield 2.9 % 3.0 % Weighted average fair value (Monte Carlo model) $ 45.60 $ 54.58 (1) The expected term was based on the service period of the award. (2) The volatility rate is based on historical stock prices over an appropriate period, generally equal to the expected term.
Stock Based Compensation	Cleco and Cleco Power reported pretax compensation expense for their share-based compensation plans as shown in the following tables: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE YEAR ENDED DEC. 31, 2015 FOR THE Equity classification Non-vested stock (1) $ — $ 3,241 $ 6,110 $ 6,308 Tax benefit $ — $ 1,247 $ 2,351 $ 2,427 (1) For each of the years ended December 31, 2015 , and 2014 , compensation expense included in Cleco’s Consolidated Statements of Income related to non-forfeitable dividends paid on non-vested stock that was not expected to vest was $0.1 million . For the predecessor period January 1, 2016, through April 12, 2016, compensation expense included in Cleco’s Consolidated Statements of Income related to non-forfeitable dividends paid on non-vested stock that was not expected to vest was less than $0.1 million .
Cleco Power [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Stock Based Compensation	Cleco Power FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Equity classification Non-vested stock $ 997 $ 2,000 $ 2,004 Tax benefit $ 384 $ 770 $ 771

Pension Plan and Employee Ben40

Pension Plan and Employee Benefits (Tables)	12 Months Ended
	Dec. 31, 2016
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Reconciliation of Benefit Obligations, Plan Assets and Funded Status of Pension Plans	The employee pension plan and other benefits obligation plan assets and funded status at December 31, 2016 , and 2015 are presented in the following table: PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE APR. 13, 2016 - JAN. 1, 2016 - FOR THE Change in benefit obligation Benefit obligation at beginning of period $ 499,724 $ 480,062 $ 498,372 $ 42,707 $ 43,070 $ 44,652 Service cost 6,909 2,563 10,419 1,112 431 1,635 Interest cost 15,088 6,242 20,795 1,237 476 1,607 Plan participants’ contributions — — — 758 300 903 Actuarial loss (gain) 6,242 16,857 (30,483 ) 2,292 — (1,039 ) Expenses paid (2,025 ) (801 ) (1,995 ) — — — Medicare D — — — — — 48 Benefits paid (13,153 ) (5,199 ) (17,046 ) (3,970 ) (1,570 ) (4,736 ) Benefit obligation at end of period 512,785 499,724 480,062 44,136 42,707 43,070 Change in plan assets Fair value of plan assets at beginning of period 398,515 383,532 412,803 — — — Actual return on plan assets 20,378 20,983 (10,230 ) — — — Expenses paid (2,025 ) (801 ) (1,995 ) — — — Benefits paid (13,153 ) (5,199 ) (17,046 ) — — — Fair value of plan assets at end of period 403,715 398,515 383,532 — — — Unfunded status $ (109,070 ) $ (101,209 ) $ (96,530 ) $ (44,136 ) $ (42,707 ) $ (43,070 )
Accumulated Benefit Obligation	The employee pension plan accumulated benefit obligation at December 31, 2016 , and 2015 is presented in the following table: PENSION BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Accumulated benefit obligation $ 473,197 $ 440,876
Amounts Recognized in Other Comprehensive Income	The following table presents the net actuarial gains/losses, transition obligations/assets, and prior service costs included in other comprehensive income for other benefits and in regulatory assets for pension related to current year gains and losses as a result of being included in net periodic benefit costs for the employee pension plan and other benefits plan at December 31, 2016 , and 2015 : PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE APR. 13, 2016 - JAN. 1, 2016 - FOR THE Net actuarial (gain) loss occurring during period $ (10,198 ) $ 16,056 $ 3,128 $ 2,292 $ — $ (1,039 ) Net actuarial loss amortized during period $ 8,138 $ 2,798 $ 13,828 $ — $ 181 $ 866 Prior service (credit) cost amortized during period $ (51 ) $ (20 ) $ (71 ) $ — $ 34 $ 119
Amounts Recognized in Accumulated Other Comprehensive Income	The following table presents net gains/losses and prior period service costs/credits in accumulated other comprehensive income for other benefits and in regulatory assets for pension that have not been recognized as components of net periodic benefit costs and the amounts expected to be recognized in 2017 for the employee pension plan and other benefits plans for December 31, 2017 , 2016 , and 2015 : PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2017 AT DEC. 31, 2016 AT DEC. 31, 2015 AT DEC. 31, 2017 AT DEC. 31, 2016 AT DEC. 31, 2015 Net actuarial loss $ 9,647 $ 145,542 $ 150,620 $ — $ 2,292 $ 8,805 Prior service (credit) cost $ (71 ) $ (274 ) $ (345 ) $ — $ — $ 363
Components of Net Periodic Pension and Other Benefit Costs	The components of net periodic pension and other benefits costs for 2016 , 2015 , and 2014 are as follows: PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE Components of periodic benefit costs Service cost $ 6,909 $ 2,563 $ 10,419 $ 8,050 $ 1,112 $ 431 $ 1,635 $ 1,542 Interest cost 15,088 6,242 20,795 19,851 1,237 476 1,607 1,809 Expected return on plan assets (17,310 ) (6,812 ) (23,382 ) (24,507 ) — — — — Amortizations Transition obligation — — — — — — — 16 Prior period service (credit) cost (51 ) (20 ) (71 ) (71 ) — 34 119 119 Net loss 8,138 2,798 13,828 6,743 — 181 866 670 Net periodic benefit cost $ 12,774 $ 4,771 $ 21,589 $ 10,066 $ 2,349 $ 1,122 $ 4,227 $ 4,156
Weighted-Average Assumptions Used to Determine Benefit Obligation and Net Periodic Costs	The assumptions used to determine the benefit obligation and the periodic costs are as follows: PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR AT DEC. 31, 2016 AT DEC. 31, 2015 AT DEC. 31, 2016 AT DEC. 31, 2015 Weighted-average assumptions used to determine the benefit obligation Discount rate 4.27 % 4.62 % 3.81 % 4.08 % Rate of compensation increase 3.03 % 3.08 % N/A N/A PENSION BENEFITS OTHER BENEFITS SUCCESSOR PREDECESSOR SUCCESSOR PREDECESSOR APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE APR. 13, 2016 - JAN. 1, 2016 - FOR THE FOR THE Weighted-average assumptions used to determine the net benefit cost Discount rate 4.21 % 4.62 % 4.21 % 5.14 % 4.08 % 4.08 % 3.76 % 4.46 % Expected return on plan assets 6.21 % 6.21 % 6.15 % 6.76 % N/A N/A N/A N/A Rate of compensation increase 3.03 % 3.03 % 3.08 % 3.17 % N/A N/A N/A N/A
Fair Value Allocation of Pension Plan Assets	The following tables disclose the pension plan’s fair value of financial assets measured on a recurring basis: SUCCESSOR (THOUSANDS) 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 Cash equivalents $ 6,817 $ — $ 6,817 $ — Common stock 19,311 19,311 — — Obligations of U.S. Government, U.S. Government Agencies, and state and local governments 47,543 — 47,543 — Mutual funds Domestic 52,663 52,663 — — International 31,191 31,191 — — Real estate funds 18,668 — — 18,668 Corporate debt 185,659 — 185,659 — Total $ 361,852 $ 103,165 $ 240,019 $ 18,668 Investments measured at net asset value* 38,886 Interest accrual 2,977 Total net assets $ 403,715 *Investments measured at net asset value consist of Common/collective trust. PREDECESSOR (THOUSANDS) AT DEC. 31, 2015 QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1) SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2) SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3) Asset Description Cash equivalents $ 4,568 $ — $ 4,568 $ — Common stock 13,816 13,816 — — Obligations of U.S. Government, U.S. Government Agencies, and state and local governments 48,792 — 48,792 — Mutual funds Domestic 47,801 47,801 — — International 22,853 22,853 — — Real estate funds 17,890 — — 17,890 Corporate debt 182,408 — 182,408 — Total $ 338,128 $ 84,470 $ 235,768 $ 17,890 Investments measured at net asset value* 42,362 Interest accrual 3,042 Total net assets $ 383,532 *Investments measured at net asset value consist of Hedge fund-of-funds and Common/collective trust. The following chart shows the dynamic asset allocation based on the funded ratio at December 31, 2016 : PERCENT OF TOTAL PLAN ASSETS MINIMUM TARGET MAXIMUM Return-seeking Domestic equity 18 % International equity 17 % Real estate 5 % Total return-seeking 35 % 40 % 45 % Liability hedging* 55 % 60 % 65 % *Liability hedging is not target by subcategories.
Pension Plan Unobservable Input Reconciliation	The following is a reconciliation of the beginning and ending balances of the pension plan’s real estate funds measured at fair value on a recurring basis using significant unobservable inputs (Level 3) during the years ended December 31, 2016 , and 2015 : (THOUSANDS) PREDECESSOR Balance, Dec. 31, 2014 $ 18,792 Realized gains 9 Unrealized losses (148 ) Purchases 679 Sales (1,442 ) Balance, Dec. 31, 2015 $ 17,890 Realized gains 71 Unrealized gains 89 Purchases 26 Sales (205 ) Balance, Apr. 12, 2016 $ 17,871 SUCCESSOR Balance, Apr. 13, 2016 $ 17,871 Realized gains 151 Unrealized gains 226 Purchases 570 Sales (151 ) Balance, Dec. 31, 2016 $ 18,668
Assumed Health Care Cost Trend Rates	A one-percentage point change in assumed health care cost trend rates would have the following effects on other benefits: ONE-PERCENTAGE POINT (THOUSANDS) INCREASE DECREASE Effect on total of service and interest cost components $ 19 $ (22 ) Effect on postretirement benefit obligation $ 238 $ (265 )
Projected Benefit Payments and Projected Receipts	The projected benefit payments for the employee pension plan and other benefits obligation plan for each year through 2021 and the next five years thereafter are listed in the following table: (THOUSANDS) PENSION BENEFITS OTHER BENEFITS, GROSS 2017 $ 20,152 $ 3,927 2018 $ 21,265 $ 3,951 2019 $ 22,382 $ 4,002 2020 $ 23,719 $ 4,006 2021 $ 24,818 $ 3,993 Next five years $ 141,584 $ 18,190
401(k) Plan Expense	Cleco’s 401(k) Plan expense for the years ended December 31, 2016 , 2015 , and 2014 is as follows: SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE 401(k) Plan expense $ 3,554 $ 1,593 $ 5,029 $ 4,730
Other Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Schedule of Amounts Recognized in Balance Sheet	The current and non-current portions of the other benefits liability for Cleco and Cleco Power at December 31, 2016 , and 2015 are as follows: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current $ 3,854 $ 3,613 Non-current $ 40,196 $ 39,457
SERP Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Reconciliation of Benefit Obligations, Plan Assets and Funded Status of Pension Plans	SERP’s funded status at December 31, 2016 , and 2015 is presented in the following table: SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - APR. 12, 2016 FOR THE Change in benefit obligation Benefit obligation at beginning of period $ 79,555 $ 72,315 $ 73,902 Service cost 571 702 2,705 Interest cost 2,275 900 3,056 Actuarial loss (gain) 1,152 — (4,488 ) Benefits paid (2,999 ) (1,186 ) (2,860 ) Plan amendments (2,509 ) Curtailments 3,602 Special/contractual termination benefits 3,222 Benefit obligation at end of period $ 78,045 $ 79,555 $ 72,315
Accumulated Benefit Obligation	SERP’s accumulated benefit obligation at December 31, 2016 , and 2015 is presented in the following table: SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Accumulated benefit obligation $ 76,194 $ 65,840
Schedule of Amounts Recognized in Balance Sheet	The current and non-current portions of the SERP liability for Cleco and Cleco Power at December 31, 2016 , and 2015 are as follows: Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current $ 4,308 $ 3,238 Non-current $ 73,738 $ 69,049
Amounts Recognized in Other Comprehensive Income	The following table presents net actuarial gains/losses and prior service costs included in other comprehensive income or regulatory assets related to current year gains and losses as a result of being amortized as a component of net periodic benefit costs for SERP at December 31, 2016 , and 2015 : SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - JAN. 1, 2016 - APR. 12, 2016 FOR THE Net actuarial gain occurring during year $ (1,345 ) $ — $ (4,487 ) Net actuarial loss amortized during year $ 1,651 $ 574 $ 2,973 Prior service (credit) cost amortized during year $ (50 ) $ 17 $ 54
Amounts Recognized in Accumulated Other Comprehensive Income	The following table presents net gains/losses and prior period service costs/credit in accumulated other comprehensive income and regulatory assets that have not been recognized as components of net periodic benefit costs and the amounts expected to be recognized in 2017 for SERP for December 31, 2017 , 2016 , and 2015 : SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2017 AT DEC. 31, 2016 AT DEC. 31, 2015 Net actuarial loss $ 1,634 $ 20,999 $ 23,763 Prior service (credit) cost $ (190 ) $ (2,368 ) $ 120
Components of Net Periodic Pension and Other Benefit Costs	The components of the net SERP costs for 2016 , 2015 , and 2014 are as follows: SERP BENEFITS SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE Components of periodic benefit costs Service cost $ 571 $ 702 $ 2,705 $ 2,278 Interest cost 2,275 900 3,056 3,028 Amortizations Prior period service (credit) cost (50 ) 17 54 54 Net loss 1,651 574 2,973 1,875 Net periodic benefit cost $ 4,447 $ 2,193 $ 8,788 $ 7,235 Curtailment charge $ — $ 3,602 $ — $ — Special/contractual termination benefits $ — $ 3,222 $ — $ — Total benefit cost $ 4,447 $ 9,017 $ 8,788 $ 7,235
Weighted-Average Assumptions Used to Determine Benefit Obligation and Net Periodic Costs	The assumptions used to determine the benefit obligation and the periodic costs are as follows: SERP SUCCESSOR PREDECESSOR AT DEC. 31, 2016 AT DEC. 31, 2015 Weighted-average assumptions used to determine the benefit obligation Discount rate 4.22 % 4.60 % Rate of compensation increase 5.00 % 5.00 % SERP SUCCESSOR PREDECESSOR SEPT. 1, 2016 - DEC. 31, 2016 APR. 13, 2016 - AUG. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE Weighted-average assumptions used to determine the net benefit cost Discount rate 3.47 % 4.15 % 4.60 % 4.20 % 5.09 % Rate of compensation increase 5.00 % 5.00 % 5.00 % 5.00 % 5.00 %
Projected Benefit Payments and Projected Receipts	The projected benefit payments for the SERP for each year through 2021 and the next five years thereafter are shown in the following table: (THOUSANDS) 2017 2018 2019 2020 2021 NEXT FIVE YEARS SERP $ 4,399 $ 4,444 $ 4,483 $ 4,558 $ 4,578 $ 23,168
Cleco Power [Member] | Other Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Schedule of Amounts Recognized in Balance Sheet	Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current $ 3,345 $ 3,140 Non-current $ 34,892 $ 34,300
Cleco Power [Member] | SERP Benefits [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
Schedule of Amounts Recognized in Balance Sheet	Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current $ 885 $ 1,000 Non-current $ 15,145 $ 21,321
Other Subsidiaries [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans [Line Items]
401(k) Plan Expense	The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the years ended December 31, 2016 , 2015 , and 2014 is as follows: SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE 401(k) Plan expense $ 554 $ 319 $ 944 $ 921

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Taxes [Line Items]
Effective Income Tax Rate Reconciliation	For the successor period April 13, 2016, through December 31, 2016 , and the predecessor period for the year ended December 31, 2015, income tax expense was higher than the amount computed by applying the statutory federal rate. For the predecessor period January 1, 2016, through April 12, 2016, and for the predecessor period for the year ended December 31, 2014 , income tax expense was lower than the amount computed by applying the statutory federal rate. The differences are as follows: SUCCESSOR PREDECESSOR (THOUSANDS, EXCEPT FOR %) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE YEAR ENDED DEC. 31, 2015 FOR THE Income before tax $ (46,935 ) $ (492 ) $ 211,373 $ 221,855 Statutory rate 35.0 % 35.0 % 35.0 % 35.0 % Tax at federal statutory rate $ (16,427 ) $ (172 ) $ 73,981 $ 77,649 Increase (decrease) Plant differences, including AFUDC flowthrough (881 ) 823 1,875 462 Amortization of investment tax credits (371 ) (124 ) (916 ) (983 ) State income taxes (4,725 ) (3,078 ) 1,117 23 Nondeductible merger costs (844 ) 4,282 — — Settlement with taxing authorities — — — (9,106 ) Return to accrual adjustment (2,943 ) — — — NMTC (181 ) (158 ) 243 (754 ) Other 3,550 1,895 1,404 (175 ) Total tax (benefit) expense $ (22,822 ) $ 3,468 $ 77,704 $ 67,116 Effective Rate 48.6 % (704.9 )% 36.8 % 30.3 %
Current and Deferred Income Tax Expense	Information about current and deferred income tax expense is as follows: SUCCESSOR PREDECESSOR (THOUSANDS) APR. 13, 2016 - DEC. 31, 2016 JAN. 1, 2016 - FOR THE FOR THE Current federal income tax (benefit) expense $ (1,062 ) $ 1,373 $ 1,284 $ 11,082 Deferred federal income tax (benefit) expense (16,715 ) 5,297 76,219 71,061 Amortization of accumulated deferred investment tax credits (371 ) (124 ) (916 ) (983 ) Total federal income tax (benefit) expense $ (18,148 ) $ 6,546 $ 76,587 $ 81,160 Current state income tax (benefit) expense (337 ) — 3,233 (6,580 ) Deferred state income tax (benefit) expense (4,337 ) (3,078 ) (2,116 ) (7,464 ) Total state income tax (benefit) expense $ (4,674 ) $ (3,078 ) $ 1,117 $ (14,044 ) Total federal and state income tax (benefit) expense $ (22,822 ) $ 3,468 $ 77,704 $ 67,116 Items charged or credited directly to member’s/shareholders’ equity Federal deferred 14,593 (277 ) 3,274 (3,656 ) State deferred 2,441 (45 ) 528 (590 ) Total tax expense (benefit) from items charged directly to member’s/shareholders’ equity $ 17,034 $ (322 ) $ 3,802 $ (4,246 ) Total federal and state income tax (benefit) expense $ (5,788 ) $ 3,146 $ 81,506 $ 62,870
Deferred Tax Assets and Liabilities	The balance of accumulated deferred federal and state income tax assets and liabilities at December 31, 2016 , and 2015 was comprised of the following: SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Depreciation and property basis differences $ (943,552 ) $ (948,597 ) Net operating loss carryforward 54,727 12,092 NMTC 89,411 87,544 Fuel costs (8,802 ) (7,833 ) Other comprehensive income 3,399 15,774 Regulated operations regulatory liability, net (91,734 ) (90,122 ) Postretirement benefits other than pension 22,733 11,561 Merger fair value adjustments (124,254 ) — Other (34,983 ) (5,522 ) Accumulated deferred federal and state income taxes, net $ (1,033,055 ) $ (925,103 )
Liability for Unrecognized Tax Benefits	The total liability for unrecognized tax benefits for Cleco at December 31, 2014 is shown in the following table: Cleco (THOUSANDS) LIABILITY FOR UNRECOGNIZED TAX BENEFITS PREDECESSOR Balance, Jan. 1, 2014 $ 5,071 Reduction for tax positions of current period — Additions for tax positions of prior years — Reduction for tax positions of prior years — Reduction for settlement with tax authority (5,071 ) Reduction for lapse of statute of limitations — Balance, Dec. 31, 2014 $ —
Cleco Power [Member]
Income Taxes [Line Items]
Effective Income Tax Rate Reconciliation	For the years ended December 31, 2016, and 2014 income tax expense was lower than the amount computed by applying the statutory rate. For the year ended December 31, 2015, income tax expense was higher than the amount computed by applying the statutory federal rate to income before tax. The differences are as follows: FOR THE YEAR ENDED DEC. 31, (THOUSANDS, EXCEPT FOR %) 2016 2015 2014 Income before tax $ 57,497 $ 220,644 $ 231,290 Statutory rate 35.0 % 35.0 % 35.0 % Tax at federal statutory rate $ 20,124 $ 77,225 $ 80,952 Increase (decrease): Plant differences, including AFUDC flowthrough (58 ) 1,875 462 Amortization of investment tax credits (494 ) (916 ) (983 ) State income taxes (2,573 ) 1,501 351 Settlement with taxing authorities — — (2,320 ) Return to accrual adjustment (2,646 ) — — Other 4,016 (391 ) (1,488 ) Total taxes $ 18,369 $ 79,294 $ 76,974 Effective Rate 31.9 % 35.9 % 33.3 %
Current and Deferred Income Tax Expense	Information about current and deferred income tax expense is as follows: FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Current federal income tax (benefit) expense $ (1,211 ) $ 33,138 $ (197 ) Deferred federal income tax expense 22,647 45,572 83,676 Amortization of accumulated deferred investment tax credits (494 ) (916 ) (983 ) Total federal income tax expense $ 20,942 $ 77,794 $ 82,496 Current state income tax (benefit) expense (418 ) 3,397 (4,161 ) Deferred state income tax benefit (2,155 ) (1,897 ) (1,361 ) Total state income tax (benefit) expense $ (2,573 ) $ 1,500 $ (5,522 ) Total federal and state income taxes $ 18,369 $ 79,294 $ 76,974 Items charged or credited directly to members’ equity Federal deferred 1,976 106 (1,137 ) State deferred 319 17 (184 ) Total tax expense (benefit) from items charged directly to member’s equity $ 2,295 $ 123 $ (1,321 ) Total federal and state income tax expense $ 20,664 $ 79,417 $ 75,653
Deferred Tax Assets and Liabilities	The balance of accumulated deferred federal and state income tax assets and liabilities at December 31, 2016 , and 2015 was comprised of the following: (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Depreciation and property basis differences $ (941,166 ) $ (944,675 ) Net operating loss carryforward (362 ) 18 Fuel costs (8,802 ) (7,833 ) Other comprehensive income 8,021 9,878 Regulated operations regulatory liability, net (91,734 ) (90,122 ) Postretirement benefits other than pension 1,288 (3,853 ) Other (35,837 ) (6,944 ) Accumulated deferred federal and state income taxes, net $ (1,068,592 ) $ (1,043,531 )

Disclosures about Segments (Tab

Disclosures about Segments (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Reporting [Abstract]
Segment Information	SEGMENT INFORMATION SUCCESSOR APR. 13, 2016 - DEC. 31, 2016 PREDECESSOR JAN. 1, 2016 - APR. 12, 2016 (THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL CLECO POWER OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 810,075 $ (7,482 ) $ (1 ) $ 802,592 $ 281,154 $ — $ — $ 281,154 Other operations 50,080 1,482 — 51,562 18,493 587 — 19,080 Electric customer credits (1,149 ) — — (1,149 ) (364 ) — — (364 ) Affiliate revenue 621 35,602 (36,223 ) — 263 15,024 (15,287 ) — Operating revenue, net $ 859,627 $ 29,602 $ (36,224 ) $ 853,005 $ 299,546 $ 15,611 $ (15,287 ) $ 299,870 Depreciation and amortization $ 102,444 $ 7,296 $ (1 ) $ 109,739 $ 43,698 $ 377 $ 1 $ 44,076 Merger transaction and commitment costs $ 151,501 $ 23,195 $ — $ 174,696 $ — $ 34,928 $ (16 ) $ 34,912 Interest charges $ 54,606 $ 35,246 $ (86 ) $ 89,766 $ 21,840 $ 295 $ (12 ) $ 22,123 Interest income $ 652 $ 275 $ (87 ) $ 840 $ 208 $ 69 $ (12 ) $ 265 Federal and state income tax expense (benefit) $ 5,376 $ (28,198 ) $ — $ (22,822 ) $ 12,993 $ (9,525 ) $ — $ 3,468 Net income (loss) $ 17,580 $ (41,692 ) $ (1 ) $ (24,113 ) $ 21,548 $ (25,508 ) $ — $ (3,960 ) Additions to property, plant, and equipment $ 143,790 $ 654 $ — $ 144,444 $ 42,353 $ 39 $ — $ 42,392 Equity investment in investee $ 18,672 $ — $ — $ 18,672 Goodwill $ 1,490,797 $ — $ — $ 1,490,797 Total segment assets $ 5,758,245 $ 614,959 $ (30,060 ) $ 6,343,144 PREDECESSOR (THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 1,142,389 $ — $ — $ 1,142,389 Other operations 67,109 2,078 (1 ) 69,186 Electric customer credits (2,173 ) — — (2,173 ) Affiliate revenue 1,142 57,323 (58,465 ) — Operating revenue, net $ 1,208,467 $ 59,401 $ (58,466 ) $ 1,209,402 Depreciation and amortization $ 147,839 $ 1,739 $ 1 $ 149,579 Merger transaction costs $ — $ 4,592 $ (1 ) $ 4,591 Interest charges $ 76,560 $ 1,149 $ 282 $ 77,991 Interest income $ 725 $ (111 ) $ 281 $ 895 Federal and state income tax expense (benefit) $ 79,294 $ (1,590 ) $ — $ 77,704 Net income (loss) $ 141,350 $ (7,681 ) $ — $ 133,669 Additions to property, plant, and equipment $ 156,357 $ 462 $ — $ 156,819 Equity investment in investee $ 16,822 $ — $ — $ 16,822 Total segment assets $ 4,233,337 $ 21,471 $ 68,546 $ 4,323,354 PREDECESSOR (THOUSANDS) CLECO POWER OTHER ELIMINATIONS TOTAL Revenue Electric operations $ 1,225,960 $ — $ — $ 1,225,960 Tolling operations — 5,467 (5,467 ) — Other operations 64,893 2,163 (1 ) 67,055 Electric customer credits (23,530 ) — — (23,530 ) Affiliate revenue 1,326 56,031 (57,357 ) — Operating revenue, net $ 1,268,649 $ 63,661 $ (62,825 ) $ 1,269,485 Depreciation and amortization $ 144,026 $ 2,479 $ — $ 146,505 Merger transaction costs $ — $ 17,848 $ — $ 17,848 Interest charges $ 74,673 $ (1,538 ) $ 471 $ 73,606 Interest income $ 1,707 $ (410 ) $ 471 $ 1,768 Federal and state income tax expense (benefit) $ 76,974 $ (9,858 ) $ — $ 67,116 Net income (loss) $ 154,316 $ 424 $ (1 ) $ 154,739 Additions to property, plant, and equipment $ 206,607 $ 1,029 $ — $ 207,636 Equity investment in investees $ 14,532 $ 8 $ — $ 14,540 Total segment assets $ 4,232,942 $ 248,043 $ (112,567 ) $ 4,368,418

Variable Interest Entities (Tab

Variable Interest Entities (Tables) - Cleco Power [Member]	12 Months Ended
	Dec. 31, 2016
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 DEC. 31, 2016 AT DEC. 31, 2015 Oxbow’s net assets/liabilities $ 37,345 $ 33,645 Cleco Power’s 50% equity $ 18,672 $ 16,822 Cleco Power’s maximum exposure to loss $ 18,672 $ 16,822
Equity Method Investments	The following table presents the components of Cleco Power’s equity investment in Oxbow: INCEPTION TO DATE (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Purchase price $ 12,873 $ 12,873 Cash contributions 6,399 3,949 Dividend received (600 ) — Total equity investment in investee $ 18,672 $ 16,822 The following tables contain summarized financial information for Oxbow: (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Current assets $ 886 $ 2,794 Property, plant, and equipment, net 25,864 23,749 Other assets 10,971 7,220 Total assets $ 37,721 $ 33,763 Current liabilities $ 376 $ 118 Partners’ capital 37,345 33,645 Total liabilities and partners’ capital $ 37,721 $ 33,763 FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Operating revenue $ 5,459 $ 3,991 $ 2,248 Operating expenses 5,459 3,991 2,248 Income before taxes $ — $ — $ —

Operating Leases (Tables)

Operating Leases (Tables)	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Summary of Expected Operating Lease Payments	The following table is a summary of expected operating lease payments for Cleco and Cleco Power: (THOUSANDS) CLECO HOLDINGS CLECO POWER TOTAL Year ending Dec. 31, 2017 $ 315 $ 6,505 $ 6,820 2018 313 2,939 3,252 2019 — 2,823 2,823 2020 — 2,801 2,801 2021 — 2,396 2,396 Thereafter — 3,301 3,301 Total operating lease payments $ 628 $ 20,765 $ 21,393

Litigation, Other Commitments45

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees (Tables) - Cleco Power [Member]	12 Months Ended
	Dec. 31, 2016
Recorded Unconditional Purchase Obligation [Line Items]
Schedule of Capital Leased Assets [Table Text Block]	The following is an analysis of leased property under capital leases by major classes: AT DEC. 31, CLASSES OF PROPERTY (THOUSANDS) 2016 2015 Barges $ 11,350 $ 11,350 Less: accumulated amortization 9,729 7,296 Net capital leases $ 1,621 $ 4,054
Recorded Unconditional Purchase Obligations [Table Text Block]	The aggregate amount of payments required under such obligations at December 31, 2016 , is as follows: YEAR ENDING DEC. 31, (THOUSANDS) 2017 $ 56,482 2018 14,905 2019 3,688 Total long-term purchase obligations $ 75,075
Schedule of Future Minimum Lease Payments for Capital Leases [Table Text Block]	The following is a schedule by years of future minimum lease payments under capital leases together with the present value of the net minimum lease payments as of December 31, 2016 : (THOUSANDS) Year ending December 31, 2017 $ 2,480 Less: executory costs 620 Net minimum lease payments 1,860 Less: amount representing interest 41 Present value of net minimum lease payments $ 1,819 Current liabilities $ 1,819

Affiliate Transactions (Tables)

Affiliate Transactions (Tables)	12 Months Ended
	Dec. 31, 2016
Cleco Power [Member]
Affiliate Transaction [Line Items]
Schedule of Related Party Transactions	The following table is a summary of charges from each affiliate included in Cleco Power’s Consolidated Statements of Income: FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Support Group Other operations $ 46,116 $ 53,079 $ 50,801 Maintenance $ 2,255 $ 1,807 $ 2,091 Taxes other than income taxes $ 10 $ (3 ) $ (9 ) Other expenses $ 106 $ 403 $ 339 Evangeline Purchased power expense $ — $ — $ 5,467 The following table shows the expense of the pension plan related to Cleco Power’s affiliates for the years ended 2016 and 2015 : FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 Support Group $ 1,771 $ 2,055 Cleco Power had the following affiliate receivable and payable balances associated with the service agreements: AT DEC. 31, 2016 AT DEC. 31, 2015 (THOUSANDS) ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE ACCOUNTS RECEIVABLE ACCOUNTS PAYABLE Cleco Holdings $ 3 $ 119 $ 653 $ 564 Support Group 1,402 7,071 1,254 6,034 Other (1) 1 — 1 — Total $ 1,406 $ 7,190 $ 1,908 $ 6,598 (1) Represents Attala and Perryville in 2016 and Attala, Diversified Lands, and Perryville in 2015. The following table is a summary of revenue received from affiliates included in Cleco Power’s Consolidated Statements of Income: FOR THE YEAR ENDED DEC. 31, (THOUSANDS) 2016 2015 2014 Affiliate revenue Support Group $ 884 $ 1,142 $ 1,322 Evangeline — — 4 Total affiliate revenue $ 884 $ 1,142 $ 1,326 Other income Cleco Holdings $ 19 $ 3 $ 30 Support Group — — 10 Evangeline — — 9 Diversified Lands — 10 14 Perryville 6 — 5 Attala 6 — 5 Total other income $ 31 $ 13 $ 73 Total $ 915 $ 1,155 $ 1,399

Intangible Assets and Goodwill

Intangible Assets and Goodwill (Tables)	12 Months Ended
	Dec. 31, 2016
Finite-Lived Intangible Assets [Line Items]
Intangible Asset, Net	The following tables summarize the balances for intangible assets subject to amortization for Cleco and Cleco Power as of December 31, 2016 , and 2015 : Cleco SUCCESSOR PREDECESSOR (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 70,594 $ 177,537 Power supply agreements 86,726 — Trade name 5,100 — Gross carrying amount 162,420 177,537 Accumulated amortization (19,786 ) (102,574 ) Net intangible assets subject to amortization $ 142,634 $ 74,963
Expected Amortization Expense	The following tables summarize the amortization expense related to intangible assets expected to be recognized in Cleco and Cleco Power’s Statements of Income: Cleco EXPECTED AMORTIZATION EXPENSE (THOUSAND) For the year ending Dec. 31, 2017 $ 28,704 2018 $ 29,564 2019 $ 31,087 2020 $ 9,935 2021 $ 9,935 Thereafter $ 33,409
Cleco Power [Member]
Finite-Lived Intangible Assets [Line Items]
Intangible Asset, Net	Cleco Power (THOUSANDS) AT DEC. 31, 2016 AT DEC. 31, 2015 Cleco Katrina/Rita right to bill and collect storm recovery charges $ 177,537 $ 177,537 Accumulated amortization (119,064 ) (102,574 ) Net intangible assets subject to amortization $ 58,473 $ 74,963
Expected Amortization Expense	Cleco Power EXPECTED AMORTIZATION EXPENSE (THOUSANDS) For the year ending Dec. 31, 2017 $ 18,009 2018 $ 19,312 2019 $ 21,152

Accumulated Other Comprehensi48

Accumulated Other Comprehensive Loss (Tables)	12 Months Ended
	Dec. 31, 2016
Accumulated Other Comprehensive Loss [Line Items]
Components of Accumulated Other Comprehensive Loss	The components of accumulated other comprehensive loss are summarized in the following tables for Cleco and Cleco Power. All amounts are reported net of income taxes. Amounts in parentheses indicate debits. Cleco (THOUSANDS) POSTRETIREMENT BENEFIT NET (LOSS) GAIN NET (LOSS) GAIN ON CASH FLOW HEDGES TOTAL AOCI PREDECESSOR Balances, Dec. 31, 2013 $ (19,725 ) $ (6,151 ) $ (25,876 ) Other comprehensive loss before reclassifications Postretirement benefit adjustments incurred during the year (9,022 ) — (9,022 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 2,021 — 2,021 Reclassification of net loss to interest charges — 212 212 Net current-period other comprehensive (loss) income (7,001 ) 212 (6,789 ) Balances, Dec. 31, 2014 $ (26,726 ) $ (5,939 ) $ (32,665 ) Other comprehensive income before reclassifications Postretirement benefit adjustments incurred during the year 2,790 — 2,790 Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 3,079 — 3,079 Reclassification of net loss to interest charges — 211 211 Net current-period other comprehensive income 5,869 211 6,080 Balances, Dec. 31, 2015 $ (20,857 ) $ (5,728 ) $ (26,585 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 587 — 587 Reclassification of net loss to interest charges — 60 60 Net current-period other comprehensive income 587 60 647 Balances, Apr. 12, 2016 $ (20,270 ) $ (5,668 ) $ (25,938 ) SUCCESSOR (1) Balances, Apr. 13, 2016 $ — $ — $ — Other comprehensive income before reclassifications Postretirement benefit adjustments incurred during the year 2,304 — 2,304 Amounts reclassified from accumulated other comprehensive income Amortization of postretirement benefit net gain (804 ) — (804 ) Net current-period other comprehensive income 1,500 — 1,500 Balances, Dec. 31, 2016 $ 1,500 $ — $ 1,500 (1) As a result of the Merger, AOCI was reduced to zero on April 13, 2016, as required by acquisition accounting.
Cleco Power [Member]
Accumulated Other Comprehensive Loss [Line Items]
Components of Accumulated Other Comprehensive Loss	Cleco Power (THOUSANDS) POSTRETIREMENT BENEFIT NET (LOSS) GAIN NET (LOSS) GAIN ON CASH FLOW HEDGES TOTAL AOCI Balances, Dec. 31, 2013 $ (9,026 ) $ (6,151 ) $ (15,177 ) Other comprehensive loss before reclassifications Postretirement benefit adjustments incurred during the year (3,344 ) — (3,344 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 1,021 — 1,021 Reclassification of net loss to interest charges — 212 212 Net current-period other comprehensive (loss) income (2,323 ) 212 (2,111 ) Balances, Dec. 31, 2014 $ (11,349 ) $ (5,939 ) $ (17,288 ) Other comprehensive loss before reclassifications Postretirement benefit adjustments incurred during the year (1,232 ) — (1,232 ) Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss 1,217 — 1,217 Reclassification of net loss to interest charges — 211 211 Net current-period other comprehensive (loss) income (15 ) 211 196 Balances, Dec. 31, 2015 $ (11,364 ) $ (5,728 ) $ (17,092 ) Other comprehensive income before reclassifications Postretirement benefit adjustments incurred during the year 3,913 — 3,913 Amounts reclassified from accumulated other comprehensive loss Amortization of postretirement benefit net loss (454 ) — (454 ) Reclassification of net loss to interest charges — 211 211 Net current-period other comprehensive income 3,459 211 3,670 Balances, Dec. 31, 2016 $ (7,905 ) $ (5,517 ) $ (13,422 )

Miscellaneous Financial Infor49

Miscellaneous Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2016
Quarterly Information [Line Items]
Quarterly Financial Information	Quarterly information for Cleco for 2016 and 2015 is shown in the following tables: 2016 PREDECESSOR SUCCESSOR 1ST QUARTER 2ND QUARTER 2ND QUARTER 3RD 4TH QUARTER (THOUSANDS) APR. 1 - APR. 12 APR. 13 - JUNE 30 Operating revenue, net $ 266,968 $ 32,903 $ 243,502 $ 342,860 $ 266,642 Operating income (loss) $ 50,192 $ (29,832 ) $ (110,148 ) $ 93,143 $ 53,299 Net income (loss) $ 19,368 $ (23,328 ) $ (81,914 ) $ 39,621 $ 18,180 Contribution from member $ — $ — $ 100,720 $ — $ — Distributions to member $ — $ — $ 28,000 $ 28,000 $ 32,765 2015 PREDECESSOR (THOUSANDS) 1ST QUARTER 2ND QUARTER 3RD QUARTER 4TH QUARTER Operating revenue, net $ 295,457 $ 289,074 $ 345,468 $ 279,403 Operating income $ 62,722 $ 69,884 $ 102,572 $ 52,162 Net income $ 26,922 $ 30,234 $ 54,663 $ 21,850
Cleco Power [Member]
Quarterly Information [Line Items]
Quarterly Financial Information	Quarterly information for Cleco Power for 2016 and 2015 is shown in the following tables: 2016 (THOUSANDS) 1ST QUARTER 2ND QUARTER 3RD QUARTER 4TH QUARTER Operating revenue, net $ 266,682 $ 278,343 $ 345,131 $ 269,017 Operating income (loss) $ 52,265 $ (81,841 ) $ 99,420 $ 59,156 Net income (loss) $ 20,879 $ (61,229 ) $ 52,572 $ 26,906 Contribution from parent $ — $ 50,000 $ — $ — Distributions to parent $ 25,000 $ 10,000 $ 50,000 $ 25,000 2015 (THOUSANDS) 1ST QUARTER 2ND QUARTER 3RD QUARTER 4TH QUARTER Operating revenue, net $ 295,271 $ 288,885 $ 345,189 $ 279,122 Operating income $ 65,670 $ 70,243 $ 103,966 $ 54,321 Net income $ 28,605 $ 31,813 $ 58,661 $ 22,270 Distributions to parent $ 25,000 $ 35,000 $ 40,000 $ 35,000

The Company (Details)

The Company (Details)	Dec. 31, 2016generationunitcustomerentityMW	Mar. 14, 2014generationunitMW
Schedule of Equity Method Investments [Line Items]
Number of transmission interconnection facility subsidiaries | entity	2
Cleco Power [Member]
Schedule of Equity Method Investments [Line Items]
Number of generating units owned | generationunit	9
Nameplate capacity (MW) | MW	3,310
Approximate number of customers served | customer	288,000
Cleco Power [Member] | Oxbow [Member]
Schedule of Equity Method Investments [Line Items]
Ownership interest received (in hundredths)	50.00%
Evangeline [Member]
Schedule of Equity Method Investments [Line Items]
Number of generating units owned | generationunit		2
Nameplate capacity (MW) | MW		775

Summary of Significant Accoun51

Summary of Significant Accounting Policies, Asset Retirement Obligation (Details) $ in Millions	1 Months Ended
	Dec. 31, 2016USD ($)
Cleco Power [Member]
Asset Retirement Obligation [Line Items]
Asset Retirement Obligation, Revision of estimate	$ 1

Summary of Significant Accoun52

Summary of Significant Accounting Policies, Property, Plant, and Equipment (Details) - USD ($)	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Apr. 13, 2016
Successor [Member]
Property, Plant, and Equipment [Abstract]
Capitalized software, net		$ 10,000,000	$ 10,000,000
Capitalized software costs, amortization		2,351,000
Property, Plant and Equipment, Net [Abstract]
Utility Plants, Production		1,866,601,000	1,866,601,000
Utility Plants, Distribution		955,126,000	955,126,000
Utility Plants, Transmission		503,996,000	503,996,000
Utility Plants, Other		146,976,000	146,976,000
Other property, plant, and equipment		3,882,000	3,882,000
Total property, plant, and equipment		3,476,581,000	3,476,581,000
Accumulated depreciation		(75,816,000)	(75,816,000)			$ 0
Net property, plant, and equipment		3,400,765,000	$ 3,400,765,000
Predecessor [Member]
Property, Plant, and Equipment [Abstract]
Capitalized software, net				$ 12,500,000
Capitalized software costs, amortization	$ 921,000			2,194,000	$ 1,397,000
Property, Plant and Equipment, Net [Abstract]
Utility Plants, Production				2,385,345,000
Utility Plants, Distribution				1,350,475,000
Utility Plants, Transmission				665,338,000
Utility Plants, Other				244,540,000
Other property, plant, and equipment				15,514,000
Total property, plant, and equipment				4,661,212,000
Accumulated depreciation				(1,536,158,000)
Net property, plant, and equipment				3,125,054,000
Minimum [Member]
Estimated Useful Lives [Abstract]
Utility Plants, Production (in years)			10 years
Utility Plants, Distribution (in years)			15 years
Utility Plants, Transmission (in years)			5 years
Utility Plants, Other (in years)			5 years
Other property, plant, and equipment (in years)			5 years
Maximum [Member]
Estimated Useful Lives [Abstract]
Utility Plants, Production (in years)			95 years
Utility Plants, Distribution (in years)			50 years
Utility Plants, Transmission (in years)			55 years
Utility Plants, Other (in years)			45 years
Other property, plant, and equipment (in years)			45 years
Acadia Unit 1 [Member] | Successor [Member]
Plant Acquisition Adjustments, Net [Abstract]
Plant acquisition adjustment		76,116,000	$ 76,116,000
Accumulated amortization		(2,287,000)	(2,287,000)
Net plant acquisition adjustment		73,829,000	73,829,000
Acadia Unit 1 [Member] | Predecessor [Member]
Plant Acquisition Adjustments, Net [Abstract]
Plant acquisition adjustment				95,578,000
Accumulated amortization				(18,567,000)
Net plant acquisition adjustment				77,011,000
Teche and Other [Member] | Successor [Member]
Plant Acquisition Adjustments, Net [Abstract]
Plant acquisition adjustment		544,000	544,000
Accumulated amortization		(183,000)	(183,000)
Net plant acquisition adjustment		361,000	361,000
Teche and Other [Member] | Predecessor [Member]
Plant Acquisition Adjustments, Net [Abstract]
Plant acquisition adjustment				5,271,000
Accumulated amortization				(4,655,000)
Net plant acquisition adjustment				616,000
Cleco Power [Member]
Property, Plant, and Equipment [Abstract]
Capitalized software costs, amortization			$ 2,405,000	$ 1,718,000	$ 1,096,000
Annual depreciation provisions expressed as a percentage of average depreciable property (in hundredths)			2.68%	2.68%	2.66%
Property, Plant and Equipment, Net [Abstract]
Utility Plants, Production		2,406,572,000	$ 2,406,572,000	$ 2,385,345,000
Utility Plants, Distribution		1,405,703,000	1,405,703,000	1,350,475,000
Utility Plants, Transmission		719,052,000	719,052,000	665,338,000
Utility Plants, Other		259,238,000	259,238,000	244,540,000
Total property, plant, and equipment		4,790,565,000	4,790,565,000	4,645,698,000
Accumulated depreciation		(1,618,241,000)	(1,618,241,000)	(1,525,298,000)
Net property, plant, and equipment		3,172,324,000	3,172,324,000	3,120,400,000
Cleco Power [Member] | Acadia Unit 1 [Member]
Plant Acquisition Adjustments, Net [Abstract]
Plant acquisition adjustment		95,578,000	95,578,000	95,578,000
Accumulated amortization		(21,749,000)	(21,749,000)	(18,567,000)
Net plant acquisition adjustment		73,829,000	73,829,000	77,011,000
Cleco Power [Member] | Teche and Other [Member]
Plant Acquisition Adjustments, Net [Abstract]
Plant acquisition adjustment		5,271,000	5,271,000	5,271,000
Accumulated amortization		(4,910,000)	(4,910,000)	(4,655,000)
Net plant acquisition adjustment		$ 361,000	$ 361,000	$ 616,000

Summary of Significant Accoun53

Summary of Significant Accounting Policies, Deferred Project Costs (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Cleco Power [Member]
Accounting Policies [Line Items]
Deferred costs for projects that are in the initial states of development	$ 5	$ 4.6

Summary of Significant Accoun54

Summary of Significant Accounting Policies, Accounts Receivable (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Concentration Risk [Line Items]
Allowance for Doubtful Accounts Receivable	$ 7.2	$ 2.7
Accounts Receivable [Member]
Concentration Risk [Line Items]
Off-balance sheet credit exposure	$ 0

Summary of Significant Accoun55

Summary of Significant Accounting Policies, Financing Receivables (Details) - Finance Leases Financing Receivable [Member] - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Accounts, Notes, Loans and Financing Receivable [Line Items]
Financing Receivable, Allowance for Credit Losses	$ 0
Successor [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Financing Receivable, Net	13,500,000
Financing Receivable, Recorded Investment, Past Due	$ 0
Predecessor [Member]
Accounts, Notes, Loans and Financing Receivable [Line Items]
Financing Receivable, Net		$ 13,500,000
Financing Receivable, Recorded Investment, Past Due		$ 0

Summary of Significant Accoun56

Summary of Significant Accounting Policies, Reserves (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Cleco Power [Member]
Accounting Policies [Line Items]
Self Insurance Reserve	$ 4.6	$ 5.5

Summary of Significant Accoun57

Summary of Significant Accounting Policies, Restricted Cash and Cash Equivalents (Details) - USD ($) $ in Thousands	1 Months Ended		3 Months Ended	9 Months Ended	12 Months Ended
	Sep. 30, 2016	Mar. 31, 2016	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Apr. 25, 2016
Katrina/Rita Storm Recovery Collections, Net of Administration Fees [Member]
Restricted Cash and Cash Equivalents [Abstract]
Increase (Decrease) in Restricted Cash					$ 21,200
Katrina Rita Bond Principal Payments [Member]
Restricted Cash and Cash Equivalents [Abstract]
Increase (Decrease) in Restricted Cash	$ (8,300)	$ (8,500)
Katrina Rita Bond Interest Payments [Member]
Restricted Cash and Cash Equivalents [Abstract]
Increase (Decrease) in Restricted Cash	$ (2,100)	$ (2,300)
Predecessor [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current						$ 9,263
Non-current						16,195
Total restricted cash and cash equivalents						25,458
Increase (Decrease) in Restricted Cash			$ (4,847)			1,341	$ 10,097
Predecessor [Member] | Cleco Katrina Rita Storm Recovery Bonds [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current						9,263
Predecessor [Member] | Diversified Lands Mitigation Escrow [Member]
Restricted Cash and Cash Equivalents [Abstract]
Non-current						21
Predecessor [Member] | Cleco Power's Future Storm Restoration Costs [Member]
Restricted Cash and Cash Equivalents [Abstract]
Non-current						16,174
Predecessor [Member] | Cleco Power's Charitable Contributions [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current						0
Non-current						0
Predecessor [Member] | Cleco Power's Rate Credit Escrow [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current						0
Non-current						0
Successor [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current				$ 23,084	23,084
Non-current				23,410	23,410
Total restricted cash and cash equivalents				46,494	46,494
Increase (Decrease) in Restricted Cash				25,884
Successor [Member] | Cleco Katrina Rita Storm Recovery Bonds [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current				9,213	9,213
Successor [Member] | Diversified Lands Mitigation Escrow [Member]
Restricted Cash and Cash Equivalents [Abstract]
Non-current				21	21
Successor [Member] | Cleco Power's Future Storm Restoration Costs [Member]
Restricted Cash and Cash Equivalents [Abstract]
Non-current				17,379	17,379
Successor [Member] | Cleco Power's Charitable Contributions [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current				1,200	1,200
Non-current				4,179	4,179
Successor [Member] | Cleco Power's Rate Credit Escrow [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current				12,671	12,671
Non-current				1,831	1,831
Cleco Power [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current				23,084	23,084	9,263
Non-current				23,389	23,389	16,174
Total restricted cash and cash equivalents				46,473	46,473	25,437
Increase (Decrease) in Restricted Cash					21,037	1,341	$ 10,097
Cleco Power [Member] | Cleco Katrina Rita Storm Recovery Bonds [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current				9,213	9,213	9,263
Cleco Power [Member] | Cleco Power's Future Storm Restoration Costs [Member]
Restricted Cash and Cash Equivalents [Abstract]
Non-current				17,379	17,379	16,174
Cleco Power [Member] | Cleco Power's Charitable Contributions [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current				1,200	1,200	0
Non-current				4,179	4,179	0
Total restricted cash and cash equivalents								$ 6,000
Increase (Decrease) in Restricted Cash					(600)
Cleco Power [Member] | Cleco Power's Rate Credit Escrow [Member]
Restricted Cash and Cash Equivalents [Abstract]
Current				12,671	12,671	0
Non-current				$ 1,831	1,831	$ 0
Total restricted cash and cash equivalents								$ 136,000
Increase (Decrease) in Restricted Cash					$ (121,500)

Summary of Significant Accoun58

Summary of Significant Accounting Policies, Equity Investments (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accounting Policies [Abstract]
Equity Method Investment, Other than Temporary Impairment	$ 0	$ 0	$ 0

Summary of Significant Accoun59

Summary of Significant Accounting Policies, Investment Tax Credits, NMTC Fund, and Accounting for Renewable Energy Tax Credits (Details)	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Period of Recognition of Gross Investment Amortization Expense	10 years
Remaining Period of Recognition of Gross Investment Amortization Expense	2 years

Summary of Significant Accoun60

Summary of Significant Accounting Policies, AFUDC (Details) - Cleco Power [Member]	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Public Utilities, General Disclosures [Line Items]
Composite AFUDC rate, including borrowed and other funds, net of tax	7.39%	7.09%	6.47%
Composite AFUDC rate, including borrowed and other funds, pre-tax	11.94%	11.46%	10.46%

Summary of Significant Accoun61

Summary of Significant Accounting Policies, Risk Management (Details) - Cleco Power [Member] $ in Millions	Dec. 31, 2016USD ($)MMBTU	Dec. 31, 2015USD ($)MMBTU
Natural Gas Derivative [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of open natural gas positions | MMBTU	0	0
Energy risk management assets
Derivative Instruments and Hedging Activities Disclosures [Line Items]
FTRs in Energy risk management asset	$ 7.9	$ 7.7
Energy risk management liabilities
Derivative Instruments and Hedging Activities Disclosures [Line Items]
FTRs in Energy risk management liability	$ 0.2	$ 0.3

Business Combinations (Details)

Business Combinations (Details) - USD ($)	Dec. 20, 2016	Nov. 01, 2016	Apr. 13, 2016	Dec. 31, 2016	Nov. 30, 2016	Dec. 31, 2016	Dec. 31, 2016	Apr. 07, 2016	Dec. 31, 2015
Business Acquisition [Line Items]
Deferred Tax Liabilities, Goodwill			$ 0
Fair Value, Adjustment Disclosure [Abstract]
Derecognized fair value adjustment and debt issuance costs related to debt redemption						$ 19,800,000
Cleco Power [Member]
Business Acquisition [Line Items]
Accumulated Depreciation				$ 1,618,241,000		1,618,241,000	$ 1,618,241,000		$ 1,525,298,000
Merger Commitments, rate credits [Member] | Louisiana Public Service Commission [Member]
Business Acquisition [Line Items]
Merger Commitments								$ 136,000,000
Merger Commitments, rate credits [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Business Acquisition [Line Items]
Merger Commitments								136,000,000
Merger Commitments, economic development contribution [Member] | Louisiana Public Service Commission [Member]
Business Acquisition [Line Items]
Merger Commitments								7,000,000
Merger Commitments, economic development contribution [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Business Acquisition [Line Items]
Merger Commitments								7,000,000
Merger Commitments, charitable contribution, disbursed over 5 years [Member] | Louisiana Public Service Commission [Member]
Business Acquisition [Line Items]
Merger Commitments								6,000,000
Merger Commitments, charitable contribution, disbursed over 5 years [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Business Acquisition [Line Items]
Merger Commitments								6,000,000
Merger Commitments, economic development contribution, disbursed over 5 years [Member] | Louisiana Public Service Commission [Member]
Business Acquisition [Line Items]
Merger Commitments								2,500,000
Merger Commitments, economic development contribution, disbursed over 5 years [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Business Acquisition [Line Items]
Merger Commitments								2,500,000
Merger Commitments, cost savings [Member] | Louisiana Public Service Commission [Member]
Business Acquisition [Line Items]
Merger Commitments								1,200,000
Merger Commitments, cost savings [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Business Acquisition [Line Items]
Merger Commitments								$ 1,200,000
Cleco Power's solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016 [Member] | Unsecured Debt [Member] | Cleco Power [Member]
Fair Value, Adjustment Disclosure [Abstract]
Extinguishment of Debt, Amount		$ 60,000,000			$ 60,000,000
Cleco Power's senior notes, 6.65%, due 2018 [Member] | Unsecured Debt [Member] | Cleco Power [Member]
Fair Value, Adjustment Disclosure [Abstract]
Extinguishment of Debt, Amount	$ 250,000,000			250,000,000
Successor [Member]
Business Acquisition [Line Items]
Accumulated Depreciation			0	75,816,000		75,816,000	75,816,000
Preliminary 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
Successor [Member] | Cleco Holdings [Member]
Business Acquisition [Line Items]
Common stock, par value (in dollars per share)			$ 1
Share price at the time of the Merger (in dollars per share)			$ 55.37
Purchase Price Consideration			$ 3,360,000,000
Successor [Member] | Property, Plant and Equipment [Member]
Fair Value, Adjustment Disclosure [Abstract]
Assets			(1,334,932,000)
Successor [Member] | Accumulated Depreciation [Member]
Fair Value, Adjustment Disclosure [Abstract]
Assets			(1,565,776,000)
Successor [Member] | Goodwill [Member]
Fair Value, Adjustment Disclosure [Abstract]
Assets			1,490,797,000
Successor [Member] | Intangible Assets [Member]
Fair Value, Adjustment Disclosure [Abstract]
Assets			91,826,000
Successor [Member] | Regulatory Assets [Member]
Fair Value, Adjustment Disclosure [Abstract]
Assets			250,409,000
Successor [Member] | Deferred Income Tax Liabilities [Member]
Fair Value, Adjustment Disclosure [Abstract]
Liabilities			126,853,000
Successor [Member] | Other Deferred Credits [Member]
Fair Value, Adjustment Disclosure [Abstract]
Liabilities			21,175,000
Successor [Member] | Long-term Debt [Member]
Fair Value, Adjustment Disclosure [Abstract]
Liabilities			198,599,000
Successor [Member] | Cash Paid to Cleco shareholders [Member] | Cleco Holdings [Member]
Business Acquisition [Line Items]
Purchase Price Consideration, Cash Paid			3,350,000,000
Successor [Member] | Cash Paid for Cleco's unvested performance-based and time-based restricted stock awards [Member] | Cleco Holdings [Member]
Business Acquisition [Line Items]
Purchase Price Consideration, Cash Paid			$ 9,500,000
Successor [Member] | Restricted Stock [Member]
Business Acquisition [Line Items]
Remaining LTIP equity awards			0
Successor [Member] | Trade Names [Member]
Preliminary Purchase Price Allocation [Abstract]
Intangible Asset, Useful Life							20 years
Predecessor [Member]
Business Acquisition [Line Items]
Common stock, par value (in dollars per share)									$ 1
Accumulated Depreciation									$ 1,536,158,000
Preliminary Purchase Price Allocation [Abstract]
Goodwill									$ 0
Predecessor [Member] | Cleco Holdings [Member]
Business Acquisition [Line Items]
Common stock, par value (in dollars per share)									$ 1

Regulatory Assets and Liabili63

Regulatory Assets and Liabilities, Summary of Regulatory Assets and Liabilities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Jun. 30, 2014	Sep. 21, 2009
Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 285,737	$ 298,806
Total regulatory assets, net	543,973	548,345
Cleco Power [Member] | PPA true-up
Regulatory Assets and Liabilities [Line Items]
Regulatory liabilities	0	(312)
Cleco Power [Member] | Total investment tax credit
Regulatory Assets and Liabilities [Line Items]
Regulatory liabilities	(1,002)	(1,633)
Cleco Power [Member] | Total federal regulatory (liability) asset — income taxes
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	(635)	5,614
Cleco Power [Member] | Total state regulatory asset — income taxes
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	112,751	105,868
Cleco Power [Member] | AFUDC
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	126,335	127,092
Cleco Power [Member] | Total regulatory assets — deferred taxes, net
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	237,449	236,941
Cleco Power [Member] | Mining costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 6,372	8,921
Remaining Recovery Period of Regulatory Assets	2 years 6 months
Cleco Power [Member] | Interest costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 4,860	5,221
Cleco Power [Member] | AROs (1)
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	2,096	2,462
Cleco Power [Member] | Postretirement costs (1)
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	145,268	150,274
Cleco Power [Member] | Tree trimming costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	5,549	6,318
Cleco Power [Member] | Training costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 6,708	6,863
Remaining Recovery Period of Regulatory Assets	43 years
Cleco Power [Member] | Surcredits, net (2)
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 5,876	9,661
Cleco Power [Member] | Amended lignite mining agreement contingency (1)
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	0	3,781
Cleco Power [Member] | AMI deferred revenue requirement
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 4,772	5,318
Remaining Recovery Period of Regulatory Assets	9 years
Cleco Power [Member] | Production operations and maintenance expenses
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 13,999	12,436		$ 25,600
Cleco Power [Member] | AFUDC equity gross-up (2)
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	70,423	71,444
Cleco Power [Member] | Acquisition costs or Transaction costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 2,442	2,548
Remaining Recovery Period of Regulatory Assets	23 years
Cleco Power [Member] | Acquisition costs or Transaction costs | Natural Gas Processing Plant [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 999	1,030
Remaining Recovery Period of Regulatory Assets	32 years 6 months
Cleco Power [Member] | Financing costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 8,663	9,032
Cleco Power [Member] | Biomass costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 18	50
Remaining Recovery Period of Regulatory Assets	6 months
Cleco Power [Member] | MISO integration costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 1,404	2,340
Remaining Recovery Period of Regulatory Assets	1 year 6 months
Cleco Power [Member] | Corporate franchise tax
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 1,308	373
Cleco Power [Member] | Acadia FRP true-up
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	0	377	$ 800
Cleco Power [Member] | MATS costs [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 4,270	0
Remaining Recovery Period of Regulatory Assets	1 year 6 months
Cleco Power [Member] | Other
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 710	357
Cleco Power [Member] | Fuel and purchased power
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	20,787	12,910
Predecessor [Member]
Regulatory Assets and Liabilities [Line Items]
Total regulatory assets, net		548,345
Predecessor [Member] | Cleco Holdings [Member] | Postretirement costs (1)
Regulatory Assets and Liabilities [Line Items]
Regulatory assets		0
Predecessor [Member] | Cleco Holdings [Member] | Financing costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets		0
Predecessor [Member] | Cleco Holdings [Member] | Fair value of long-term debt [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory assets		0
Predecessor [Member] | Cleco Holdings [Member] | Debt issuance cost [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory assets		$ 0
Successor [Member]
Regulatory Assets and Liabilities [Line Items]
Total regulatory assets, net	739,683
Successor [Member] | Cleco Holdings [Member] | Postretirement costs (1)
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	23,362
Successor [Member] | Cleco Holdings [Member] | Financing costs
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	8,966
Successor [Member] | Cleco Holdings [Member] | Fair value of long-term debt [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	155,776
Successor [Member] | Cleco Holdings [Member] | Debt issuance cost [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory assets	$ 7,606

Regulatory Assets and Liabili64

Regulatory Assets and Liabilities, Additional Disclosures (Details) $ in Thousands	Dec. 20, 2016USD ($)	Nov. 01, 2016USD ($)	Jun. 18, 2014USD ($)	Dec. 31, 2016USD ($)	Nov. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Mar. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Jan. 31, 2013USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Jun. 30, 2014USD ($)	Dec. 31, 2011USD ($)Locks	Dec. 31, 2009USD ($)	Oct. 31, 2016USD ($)	Feb. 01, 2016USD ($)	May 31, 2013USD ($)	Feb. 28, 2011USD ($)	Sep. 21, 2009USD ($)	Apr. 30, 2009
Regulatory Assets and Liabilities [Line Items]
Derecognized fair value adjustment and debt issuance costs related to debt redemption											$ 19,800
Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets				$ 285,737		$ 298,806					285,737	$ 285,737	$ 285,737	$ 298,806
Net retail portion of franchise taxes paid													(2,573)	1,500	$ (5,522)
Increase (Decrease) in deferred fuel costs													7,215	(9,899)	11,558
Treasury Lock [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Number of Interest Rate Derivatives Held | Locks																	2
Gain (Loss) on Sale of Derivatives																	$ 26,800
Interest Rate Swap [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Gain (Loss) on Sale of Derivatives															$ 3,300
PPA true-up | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Amount recovered above the actual PPA capacity costs				0		312					0	0	$ 0	312
PPA true-up | Evangeline Power Purchase Agreement [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													12 months
Amount recovered above the actual PPA capacity costs																$ 600
Mining costs | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													11 years 6 months
Regulatory Assets				6,372		8,921					6,372	6,372	$ 6,372	8,921
Postretirement costs (1) | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													10 years
Regulatory Assets				145,268		150,274					145,268	145,268	$ 145,268	150,274
Tree trimming costs | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													3 years 6 months
Anticipated removal costs												20,800
Public Utilities, Approved Amount										$ 8,000
Regulatory Assets				5,549		6,318					5,549	5,549	$ 5,549	6,318
Anticipated removal costs to be expensed												4,000
Anticipated amount of removal costs to be deferred and recovered												5,900
Training costs | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													50 years
Regulatory Assets				6,708		6,863					6,708	6,708	$ 6,708	6,863
Surcredits, net (2) | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													4 years
Withdrawal from restricted storm reserve								$ 4,000
Regulatory Assets				5,876		9,661					5,876	5,876	$ 5,876	9,661
Amended lignite mining agreement contingency (1) | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Ownership interest (in hundredths)																								50.00%
Payments to Acquire Businesses, Gross																		$ 25,700
Percentage of loans and lease payments guaranteed by Cleco Power (in hundredths)																		50.00%
Liability recognized for guarantee of loan and lease payments																		$ 3,800
Regulatory Assets				0		3,781					0	0	0	3,781
AMI deferred revenue requirement | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets				4,772		5,318					4,772	4,772	$ 4,772	5,318
AMI deferred revenue requirement | Maximum [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													11 years
Regulatory Assets																						$ 20,000
Production operations and maintenance expenses | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													3 years
Increase (Decrease) in Other Regulatory Assets				7,300		1,800	$ 7,700		$ 8,500
Regulatory Assets				13,999		12,436					13,999	13,999	$ 13,999	12,436									$ 25,600
Production operations and maintenance expenses | Maximum [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets																							$ 23,000
Utilities Operating Expense, Maintenance and Operations			$ 45,000
Acquisition costs or Transaction costs | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													30 years
Regulatory Assets				2,442		2,548					2,442	2,442	$ 2,442	2,548
Acquisition costs or Transaction costs | Natural Gas Processing Plant [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													35 years
Regulatory Assets				999		1,030					999	999	$ 999	1,030
Financing costs | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets				8,663		9,032					8,663	8,663	$ 8,663	9,032
Financing costs | Treasury Lock [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets																	$ 7,400
Financing costs | Interest Rate Swap [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets																					$ 2,900
Biomass costs | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													5 years
Regulatory Assets				18		50					18	18	$ 18	50
MISO integration costs | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													4 years
Regulatory Assets				1,404		2,340					1,404	1,404	$ 1,404	2,340
Corporate franchise tax Retail portion | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Net retail portion of franchise taxes paid													$ 2,500	1,700
Corporate franchise tax | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													12 months
Regulatory Assets				1,308		373					1,308	1,308	$ 1,308	373
Acadia FRP true-up | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													12 months
Public Utilities, Approved Amount																58,300
Regulatory Assets				0		377					0	0	$ 0	377		$ 800
MATS costs [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets				4,270		0					4,270	4,270	4,270	0
Other | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets				710		357					710	710	710	357
Fuel and purchased power | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Assets				20,787		$ 12,910					$ 20,787	$ 20,787	$ 20,787	$ 12,910
Percentage of total fuel cost regulated by the LPSC (in hundredths)													75.00%
Increase (Decrease) in deferred fuel costs													$ 7,900
Increase (Decrease) in the mark-to-market value of FTRs													(3,600)
Deferred Fuel Costs, surcharge adjustment, environmental expenses, and timing of collections [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Increase (Decrease) in deferred fuel costs													$ 11,500
Approved Removal Costs Deferral [Member] | Tree trimming costs | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Maximum amount of costs approved to expend and defer																			$ 10,900
Approved MATS Recovery [Member] | MATS costs [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													3 years
Regulatory Assets																				$ 7,100
Approved recovery [Member] | Other | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Regulatory Noncurrent Asset, Amortization Period													3 years
Cleco Power's solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016 [Member] | Unsecured Debt [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Extinguishment of Debt, Amount		$ 60,000			$ 60,000
Cleco Power's senior notes, 6.65%, due 2018 [Member] | Unsecured Debt [Member] | Cleco Power [Member]
Regulatory Assets and Liabilities [Line Items]
Extinguishment of Debt, Amount	$ 250,000			$ 250,000

Jointly Owned Generation Unit65

Jointly Owned Generation Units (Details)	Dec. 31, 2016USD ($)MW	Apr. 13, 2016USD ($)
Cleco Power [Member]
Jointly Owned Utility Plant Interests [Line Items]
Utility plant in service	$ 539,014,000
Accumulated depreciation	298,990,000
Construction work in progress	$ 3,359,000
Nameplate capacity (MW) | MW	3,310
Cleco Power [Member] | Rodemacher Unit #2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Utility plant in service	$ 144,316,000
Accumulated depreciation	75,710,000
Construction work in progress	$ 166,000
Ownership interest percentage (in hundredths)	30.00%
Nameplate capacity (MW) | MW	523
Ownership interest (MW) | MW	157
Cleco Power [Member] | Dolet Hills [Member]
Jointly Owned Utility Plant Interests [Line Items]
Utility plant in service	$ 394,698,000
Accumulated depreciation	223,280,000
Construction work in progress	$ 3,193,000
Ownership interest percentage (in hundredths)	50.00%
Nameplate capacity (MW) | MW	650
Ownership interest (MW) | MW	325
Successor [Member]
Jointly Owned Utility Plant Interests [Line Items]
Utility plant in service	$ 247,337,000
Accumulated depreciation	7,313,000	$ 0
Construction work in progress	3,359,000
Successor [Member] | Rodemacher Unit #2 [Member]
Jointly Owned Utility Plant Interests [Line Items]
Utility plant in service	70,136,000
Accumulated depreciation	1,530,000
Construction work in progress	$ 166,000
Ownership interest percentage (in hundredths)	30.00%
Nameplate capacity (MW) | MW	523
Ownership interest (MW) | MW	157
Successor [Member] | Dolet Hills [Member]
Jointly Owned Utility Plant Interests [Line Items]
Utility plant in service	$ 177,201,000
Accumulated depreciation	5,783,000
Construction work in progress	$ 3,193,000
Ownership interest percentage (in hundredths)	50.00%
Nameplate capacity (MW) | MW	650
Ownership interest (MW) | MW	325

Fair Value Accounting, Carrying

Fair Value Accounting, Carrying Value and Estimated Fair Value (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Cleco Power [Member]
Financial instruments not marked-to-market [Abstract]
Deferred debt issuance costs not included in the carrying value of long-term debt	$ 9,421	$ 9,609
Cleco Power [Member] | Estimated Fair Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt	1,418,693	1,429,989
Cleco Power [Member] | Carrying Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt	1,262,373	1,265,529
Successor [Member]
Financial instruments not marked-to-market [Abstract]
Deferred debt issuance costs not included in the carrying value of long-term debt	11,700
Successor [Member] | Estimated Fair Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt	2,754,518
Successor [Member] | Carrying Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt	$ 2,768,149
Predecessor [Member]
Financial instruments not marked-to-market [Abstract]
Deferred debt issuance costs not included in the carrying value of long-term debt		9,900
Predecessor [Member] | Estimated Fair Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt		1,463,989
Predecessor [Member] | Carrying Value [Member]
Financial instruments not marked-to-market [Abstract]
Long-term debt		$ 1,299,529

Fair Value Accounting, Fair Val

Fair Value Accounting, Fair Value Measurements and Disclosures (Details)	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016USD ($)	Dec. 31, 2016USD ($)$ / MW	Dec. 31, 2016USD ($)$ / MW	Dec. 31, 2015USD ($)$ / MW
Cleco Power [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
FTR Forward Price - per MWh, Low | $ / MW		(3.61)	(3.61)	(3.63)
FTR Forward Price - per MWh, High | $ / MW		6.04	6.04	4.51
Fair Value, Concentration of Risk, Amount of Money Market Funds in Cash and Cash Equivalents		$ 18,700,000	$ 18,700,000	$ 62,000,000
FTRs [Member] | Cleco Power [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	$ 7,398,000		7,398,000	9,949,000
Unrealized gains (losses)			2,088,000	(1,476,000)
Purchases			14,966,000	20,319,000
Settlements			(16,769,000)	(21,394,000)
Ending balance		7,683,000	7,683,000	7,398,000
Measured On A Recurring Basis [Member] | Cleco Power [Member]
Asset Description
Institutional money market funds		65,089,000	65,089,000	87,363,000
FTR assets		7,884,000	7,884,000	7,673,000
Total Assets		72,973,000	72,973,000	95,036,000
Liability Description
Long-term debt		1,418,693,000	1,418,693,000	1,429,989,000
FTR liabilities		201,000	201,000	275,000
Total Liabilities		1,418,894,000	1,418,894,000	1,430,264,000
Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Cleco Power [Member]
Asset Description
Institutional money market funds		0	0	0
FTR assets		0	0	0
Total Assets		0	0	0
Liability Description
Long-term debt		0	0	0
FTR liabilities		0	0	0
Total Liabilities		0	0	0
Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Cleco Power [Member]
Asset Description
Institutional money market funds		65,089,000	65,089,000	87,363,000
FTR assets		0	0	0
Total Assets		65,089,000	65,089,000	87,363,000
Liability Description
Long-term debt		1,418,693,000	1,418,693,000	1,429,989,000
FTR liabilities		0	0	0
Total Liabilities		1,418,693,000	1,418,693,000	1,429,989,000
Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member] | Cleco Power [Member]
Asset Description
Institutional money market funds		0	0	0
FTR assets		7,884,000	7,884,000	7,673,000
Total Assets		7,884,000	7,884,000	7,673,000
Liability Description
Long-term debt		0	0	0
FTR liabilities		201,000	201,000	275,000
Total Liabilities		201,000	201,000	275,000
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		23,100,000	23,100,000	9,300,000
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		$ 23,300,000	$ 23,300,000	$ 16,100,000
Successor [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
FTR Forward Price - per MWh, Low | $ / MW		(3.61)	(3.61)
FTR Forward Price - per MWh, High | $ / MW		6.04	6.04
Fair Value, Concentration of Risk, Amount of Money Market Funds in Cash and Cash Equivalents		$ 20,000,000	$ 20,000,000
Fair Value, Assets and Liabilities, Transfers between Levels, Amount		0	0
Successor [Member] | FTRs [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance		3,458,000
Unrealized gains (losses)		3,119,000
Purchases		12,896,000
Settlements		(11,790,000)
Ending balance	3,458,000	7,683,000	7,683,000
Successor [Member] | Measured On A Recurring Basis [Member]
Asset Description
Institutional money market funds		66,410,000	66,410,000
FTR assets		7,884,000	7,884,000
Total Assets		74,294,000	74,294,000
Liability Description
Long-term debt		2,754,518,000	2,754,518,000
FTR liabilities		201,000	201,000
Total Liabilities		2,754,719,000	2,754,719,000
Successor [Member] | Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]
Asset Description
Institutional money market funds		0	0
FTR assets		0	0
Total Assets		0	0
Liability Description
Long-term debt		0	0
FTR liabilities		0	0
Total Liabilities		0	0
Successor [Member] | Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member]
Asset Description
Institutional money market funds		66,410,000	66,410,000
FTR assets		0	0
Total Assets		66,410,000	66,410,000
Liability Description
Long-term debt		2,754,518,000	2,754,518,000
FTR liabilities		0	0
Total Liabilities		2,754,518,000	2,754,518,000
Successor [Member] | Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member]
Asset Description
Institutional money market funds		0	0
FTR assets		7,884,000	7,884,000
Total Assets		7,884,000	7,884,000
Liability Description
Long-term debt		0	0
FTR liabilities		201,000	201,000
Total Liabilities		201,000	201,000
Successor [Member] | 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		23,100,000	23,100,000
Successor [Member] | 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		23,300,000	23,300,000
Predecessor [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
FTR Forward Price - per MWh, Low | $ / MW				(3.63)
FTR Forward Price - per MWh, High | $ / MW				4.51
Fair Value, Concentration of Risk, Amount of Money Market Funds in Cash and Cash Equivalents				$ 64,200,000
Fair Value, Assets and Liabilities, Transfers between Levels, Amount				0
Predecessor [Member] | FTRs [Member]
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation [Roll Forward]
Beginning balance	7,398,000	3,458,000	7,398,000	9,949,000
Unrealized gains (losses)	(1,031,000)			(1,476,000)
Purchases	2,070,000			20,319,000
Settlements	(4,979,000)			(21,394,000)
Ending balance	$ 3,458,000			7,398,000
Predecessor [Member] | Measured On A Recurring Basis [Member]
Asset Description
Institutional money market funds				89,584,000
FTR assets				7,673,000
Total Assets				97,257,000
Liability Description
Long-term debt				1,463,989,000
FTR liabilities				275,000
Total Liabilities				1,464,264,000
Predecessor [Member] | Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]
Asset Description
Institutional money market funds				0
FTR assets				0
Total Assets				0
Liability Description
Long-term debt				0
FTR liabilities				0
Total Liabilities				0
Predecessor [Member] | Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member]
Asset Description
Institutional money market funds				89,584,000
FTR assets				0
Total Assets				89,584,000
Liability Description
Long-term debt				1,463,989,000
FTR liabilities				0
Total Liabilities				1,463,989,000
Predecessor [Member] | Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member]
Asset Description
Institutional money market funds				0
FTR assets				7,673,000
Total Assets				7,673,000
Liability Description
Long-term debt				0
FTR liabilities				275,000
Total Liabilities				275,000
Predecessor [Member] | 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				9,300,000
Predecessor [Member] | 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				16,100,000
Derivatives Not Designated as Hedging Instrument [Member] | Energy risk management asset [Member] | Measured On A Recurring Basis [Member] | FTRs [Member] | Significant Unobservable Inputs (Level 3) [Member] | Cleco Power [Member]
Liability Description
FTRs in Energy risk management assets		7,884,000	7,884,000	7,673,000
Derivatives Not Designated as Hedging Instrument [Member] | Energy risk management liabilities [Member] | Measured On A Recurring Basis [Member] | FTRs [Member] | Significant Unobservable Inputs (Level 3) [Member] | Cleco Power [Member]
Liability Description
FTRs in Energy risk management liabilities		201,000	201,000	275,000
Derivatives Not Designated as Hedging Instrument [Member] | Successor [Member] | Energy risk management asset [Member] | FTRs [Member]
Liability Description
FTRs in Energy risk management assets		7,884,000	7,884,000
Derivatives Not Designated as Hedging Instrument [Member] | Successor [Member] | Energy risk management liabilities [Member] | FTRs [Member]
Liability Description
FTRs in Energy risk management liabilities		$ 201,000	$ 201,000
Derivatives Not Designated as Hedging Instrument [Member] | Predecessor [Member] | Energy risk management asset [Member] | FTRs [Member]
Liability Description
FTRs in Energy risk management assets				7,673,000
Derivatives Not Designated as Hedging Instrument [Member] | Predecessor [Member] | Energy risk management liabilities [Member] | FTRs [Member]
Liability Description
FTRs in Energy risk management liabilities				$ 275,000

Fair Value Accounting, Commodit

Fair Value Accounting, Commodity Contracts (Details) $ in Thousands, MWh in Millions	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016USD ($)	Dec. 31, 2016USD ($)MWhMMBTU	Dec. 31, 2016USD ($)MWhMMBTU	Dec. 31, 2015USD ($)MWhMMBTU	Dec. 31, 2014USD ($)
Price Risk Derivative [Member] | Cleco Power [Member] | Derivatives Not Designated as Hedging Instrument [Member]
FTRs, at Fair Value, Net [Abstract]
Commodity-related contracts, net		$ 7,683	$ 7,683	$ 7,398
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income			18,776	23,085	$ 28,068
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	(1,500)	(2,700)
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			(20,702)	27,509	46,386
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			$ 39,478	$ 50,594	74,454
ERROR in label resolution. | Cleco Power [Member]
FTRs [Abstract]
Number of open natural gas positions | MMBTU		0	0	0
Cleco Power [Member]
FTRs [Abstract]
Number of FTRs Held (MWh) | MWh		9	9	8.4
Predecessor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated as Hedging Instrument [Member]
FTRs, at Fair Value, Net [Abstract]
Commodity-related contracts, net				$ 7,398
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income	$ 2,802			23,085	28,068
Predecessor [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	(1,000)			(1,500)	(2,700)
Predecessor [Member] | 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				7,673
Predecessor [Member] | 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				275
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	(5,761)			(27,509)	(46,386)
Predecessor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated as Hedging Instrument [Member] | Electric operations [Member]
FTRs [Abstract]
Gain on FTRs recognized in income	$ 8,563			50,594	$ 74,454
Successor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated as Hedging Instrument [Member]
FTRs, at Fair Value, Net [Abstract]
Commodity-related contracts, net		$ 7,683	$ 7,683
FTRs [Abstract]
Net gain (loss) on FTRs recognized in income		15,974
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		3,100
Successor [Member] | 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		7,884	7,884
Successor [Member] | 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		201	201
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		(14,941)
Successor [Member] | Price Risk Derivative [Member] | Derivatives Not Designated as Hedging Instrument [Member] | Electric operations [Member]
FTRs [Abstract]
Gain on FTRs recognized in income		30,915
Significant Unobservable Inputs (Level 3) [Member] | Measured On A Recurring Basis [Member] | 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		7,884	7,884	7,673
Significant Unobservable Inputs (Level 3) [Member] | Measured On A Recurring Basis [Member] | 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		$ 201	$ 201	$ 275

Debt, Total Indebtedness (Detai

Debt, Total Indebtedness (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	$ 1,268,715,000	$ 1,265,529,000
Long-term Line of Credit	0
Barge Lease Obligations	1,819,000	4,425,000
Gross amount of long-term debt	1,270,534,000	1,269,954,000
Less: Long-term Debt due within one year	17,896,000	16,814,000
Less: lease obligations classified as long-term debt due within one year	1,819,000	2,607,000
Unamortized Debt Discount	(6,342,000)	(6,885,000)
Unamortized Debt Issuance Costs	(9,421,000)	(9,609,000)
Long-term debt, net	1,235,056,000	1,234,039,000
Cleco Power's senior notes, 6.65%, due 2018 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	0	250,000,000
Cleco Power's senior notes, 3.68%, due 2025 [Member] [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	75,000,000	75,000,000
Cleco Power's senior notes, 3.47%, due 2026 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	130,000,000	0
Cleco Powers Senior Notes 4.33% due 2027 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	50,000,000	50,000,000
Cleco Power's senior notes, 3.57%, due 2028 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	200,000,000	0
Cleco Power's senior notes, 6.50%, due 2035 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	295,000,000	295,000,000
Cleco Power's senior notes, 6.00%, due 2040 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	250,000,000	250,000,000
Cleco Power's senior notes 5.12% due 2041 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	100,000,000	100,000,000
Series A GO Zone bonds, 2.00%, due 2038, mandatory tender in 2020 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	50,000,000	50,000,000
Series B GO Zone bonds, 4.25%, due 2036 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	50,000,000	50,000,000
Cleco Power's solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	0	60,000,000
Cleco Katrina/Rita's storm recovery bonds, 4.41%, due 2020 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	1,115,000	17,929,000
Cleco Katrina/Rita's storm recovery bonds, 5.61%, due 2023 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Unsecured Debt	67,600,000	67,600,000
Cleco Katrina Rita Storm Recovery Bonds [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Less: Long-term Debt due within one year	17,900,000
Successor [Member]
Debt Instrument [Line Items]
Less: lease obligations classified as long-term debt due within one year	1,800,000
Unamortized Debt Issuance Costs	(11,700,000)
Long-term debt, net	2,738,571,000
Successor [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Long-term Line of Credit	0
Unamortized Debt Issuance Costs	(2,261,000)
Long Term Debt. Reconciliation, Fair Value Adjustment	155,776,000
Successor [Member] | Cleco Holdings' senior notes, 3.250%, due 2023 [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Unsecured Debt	165,000,000
Successor [Member] | Cleco Katrina Rita Storm Recovery Bonds [Member]
Debt Instrument [Line Items]
Less: Long-term Debt due within one year	17,900,000
Successor [Member] | Cleco Holdings' senior notes, 3.743%, due 2026 [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Unsecured Debt	535,000,000
Successor [Member] | Cleco Holdings' senior notes, 4.973%, due 2046 [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Unsecured Debt	350,000,000
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2021 [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Bank Term Loan	$ 300,000,000
Predecessor [Member]
Debt Instrument [Line Items]
Unamortized Debt Issuance Costs		(9,900,000)
Long-term debt, net		1,267,703,000
Predecessor [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Long-term Line of Credit		34,000,000
Unamortized Debt Issuance Costs		(336,000)
Long Term Debt. Reconciliation, Fair Value Adjustment		0
Predecessor [Member] | Cleco Holdings' senior notes, 3.250%, due 2023 [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Unsecured Debt		0
Predecessor [Member] | Cleco Holdings' senior notes, 3.743%, due 2026 [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Unsecured Debt		0
Predecessor [Member] | Cleco Holdings' senior notes, 4.973%, due 2046 [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Unsecured Debt		0
Predecessor [Member] | Cleco Corporate Holdings debt, variable rate, due 2021 [Member] | Cleco Holdings [Member]
Debt Instrument [Line Items]
Bank Term Loan		$ 0

Debt, Principal amounts payable

Debt, Principal amounts payable under long-term debt agreement(Details) $ in Thousands	Dec. 31, 2016USD ($)
Cleco Power [Member]
Debt Instrument [Line Items]
2,017	$ 17,896
2,018	19,193
2,019	20,571
2,020	11,055
2,021	0
Thereafter	1,200,000
Successor [Member]
Debt Instrument [Line Items]
2,017	17,896
2,018	19,193
2,019	20,571
2,020	11,055
2,021	300,000
Thereafter	$ 2,250,000

Debt, Capital Lease Agreements

Debt, Capital Lease Agreements (Details) $ in Millions	Dec. 31, 2016USD ($)
Cleco Power [Member]
Debt Instrument [Line Items]
2,017	$ 1.8
Successor [Member]
Debt Instrument [Line Items]
2,017	$ 1.8

Debt, Additional Disclosures (D

Debt, Additional Disclosures (Details) - USD ($)	Dec. 20, 2016	Nov. 01, 2016	Jun. 28, 2016	Apr. 13, 2016	Dec. 31, 2016	Nov. 30, 2016	May 24, 2016	May 17, 2016	Dec. 31, 2015
Cleco Power [Member]
Debt [Line Items]
Short-term debt outstanding					$ 0				$ 0
Long-term Debt and Capital Lease Obligations, Including Current Maturities					1,250,000,000
Long-term Debt and Capital Lease Obligations, Current					19,715,000				19,421,000
Long-term Debt, principal payments for CKR bonds					17,896,000				16,814,000
Capital lease payments/Current liabilities					1,819,000				2,607,000
Unsecured Debt					1,268,715,000				1,265,529,000
Debt Instrument, Fee Amount					9,421,000				9,609,000
Cleco Katrina Rita Storm Recovery Bonds [Member] | Cleco Power [Member]
Debt [Line Items]
Long-term Debt, principal payments for CKR bonds					17,900,000
Cleco Power's solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016 [Member] | Cleco Power [Member]
Debt [Line Items]
Unsecured Debt					0				60,000,000
Cleco Power's senior notes, 3.47%, due 2026 [Member] | Cleco Power [Member]
Debt [Line Items]
Unsecured Debt					130,000,000				0
Debt Instrument, Face Amount	$ 130,000,000
Cleco Power's senior notes, 3.57%, due 2028 [Member] | Cleco Power [Member]
Debt [Line Items]
Unsecured Debt					200,000,000				0
Debt Instrument, Face Amount	200,000,000
Cleco Power's senior notes, 6.65%, due 2018 [Member] | Cleco Power [Member]
Debt [Line Items]
Unsecured Debt					0				250,000,000
2008 Series A GO Zone bonds | Cleco Power [Member]
Debt [Line Items]
Unsecured Debt					50,000,000				50,000,000
Cleco Power's senior notes, 3.68%, due 2025 [Member] [Member] | Cleco Power [Member]
Debt [Line Items]
Unsecured Debt					75,000,000				75,000,000
Unsecured Debt [Member] | Cleco Power's solid waste disposal facility bonds, 4.70%, due 2036, callable after November 1, 2016 [Member] | Cleco Power [Member]
Debt [Line Items]
Extinguishment of Debt, Amount		$ 60,000,000				$ 60,000,000
Interest Expense, Debt		$ 1,400,000
Unsecured Debt [Member] | Cleco Power's senior notes, 6.65%, due 2018 [Member] | Cleco Power [Member]
Debt [Line Items]
Extinguishment of Debt, Amount	250,000,000				250,000,000
Call Premium, Debt	$ 19,000,000
Successor [Member]
Debt [Line Items]
Short-term debt outstanding					0
Long-term Debt and Capital Lease Obligations, Including Current Maturities					2,760,000,000
Long-term Debt and Capital Lease Obligations, Current					19,715,000
Capital lease payments/Current liabilities					1,800,000
Debt Instrument, Fee Amount					11,700,000
Successor [Member] | Cleco Holdings [Member]
Debt [Line Items]
Short-term debt outstanding					0
Long-term Debt and Capital Lease Obligations, Including Current Maturities					1,340,000,000
Long-term Debt and Capital Lease Obligations, Current					0
Debt Instrument, Fee Amount					2,261,000
Successor [Member] | Cleco Katrina Rita Storm Recovery Bonds [Member]
Debt [Line Items]
Long-term Debt, principal payments for CKR bonds					17,900,000
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Debt Instrument, Face Amount				$ 1,350,000,000
Debt Instrument, Term				3 years
Successor [Member] | Cleco Holdings' senior notes, 3.743%, due 2026 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Unsecured Debt					535,000,000
Debt Instrument, Face Amount								$ 535,000,000
Debt Instrument, Interest Rate, Stated Percentage								3.743%
Successor [Member] | Cleco Holdings' senior notes, 4.973%, due 2046 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Unsecured Debt					350,000,000
Debt Instrument, Face Amount								$ 350,000,000
Debt Instrument, Interest Rate, Stated Percentage								4.973%
Successor [Member] | Cleco Holdings' senior notes, 3.250%, due 2023 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Unsecured Debt					$ 165,000,000
Debt Instrument, Face Amount							$ 165,000,000
Debt Instrument, Interest Rate, Stated Percentage							3.25%
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2021 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Debt Instrument, Face Amount			$ 300,000,000
Successor [Member] | Debt Issuance Cost Amortization [Member] | Cleco Holdings [Member]
Debt [Line Items]
Debt Instrument, Fee Amount				$ 17,700,000
Successor [Member] | London Interbank Offered Rate (LIBOR) [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Debt Instrument, Basis Spread on Variable Rate				1.75%
Successor [Member] | London Interbank Offered Rate (LIBOR) [Member] | Cleco Corporate Holdings debt, variable rate, due 2021 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Debt Instrument, Basis Spread on Variable Rate			1.625%
Debt Instrument, Interest Rate, Stated Percentage					2.265%
Successor [Member] | ABR [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Debt Instrument, Basis Spread on Variable Rate				0.75%
Successor [Member] | ABR [Member] | Cleco Corporate Holdings debt, variable rate, due 2021 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Debt Instrument, Basis Spread on Variable Rate			0.625%
Predecessor [Member]
Debt [Line Items]
Short-term debt outstanding									0
Long-term Debt and Capital Lease Obligations, Current									19,421,000
Debt Instrument, Fee Amount									9,900,000
Predecessor [Member] | Cleco Holdings [Member]
Debt [Line Items]
Short-term debt outstanding									0
Debt Instrument, Fee Amount									336,000
Predecessor [Member] | Cleco Holdings' senior notes, 3.743%, due 2026 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Unsecured Debt									0
Predecessor [Member] | Cleco Holdings' senior notes, 4.973%, due 2046 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Unsecured Debt									0
Predecessor [Member] | Cleco Holdings' senior notes, 3.250%, due 2023 [Member] | Cleco Holdings [Member]
Debt [Line Items]
Unsecured Debt									$ 0

Debt, Credit Facilities (Detail

Debt, Credit Facilities (Details)	Apr. 13, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Cleco Power [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 300,000,000	$ 300,000,000
Long-term Line of Credit		$ 0
Commitment fees (in hundredths)		0.125%
Letters of Credit Outstanding, Amount		$ 2,000,000
Cleco Power [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Ratio of indebtedness to net capital (in hundredths)		0.65
Cleco Power [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Unrestricted member's equity		$ 853,400,000
Cleco Power [Member] | Line of Credit [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Ratio of indebtedness to net capital (in hundredths)		0.65
Cleco Power [Member] | Line of Credit [Member] | ABR [Member]
Line of Credit Facility [Line Items]
Credit facility, Basis Spread on Variable Rate (in hundredths)		0.125%
Cleco Power [Member] | Line of Credit [Member] | LIBOR [Member]
Line of Credit Facility [Line Items]
Credit facility, Basis Spread on Variable Rate (in hundredths)		1.125%
Predecessor [Member] | Cleco Holdings [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity			250,000,000
Long-term Line of Credit			$ 34,000,000
Successor [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity		$ 400,000,000
Successor [Member] | Cleco Holdings [Member]
Line of Credit Facility [Line Items]
Maximum borrowing capacity	$ 100,000,000	100,000,000
Long-term Line of Credit		$ 0
Commitment fees (in hundredths)		0.275%
Successor [Member] | Cleco Holdings [Member] | Line of Credit [Member]
Line of Credit Facility [Line Items]
Unrestricted member's equity		$ 634,600,000
Successor [Member] | Cleco Holdings [Member] | Line of Credit [Member] | Maximum [Member]
Line of Credit Facility [Line Items]
Ratio of indebtedness to net capital (in hundredths)		0.65
Successor [Member] | Cleco Holdings [Member] | Line of Credit [Member] | ABR [Member]
Line of Credit Facility [Line Items]
Credit facility, Basis Spread on Variable Rate (in hundredths)		0.75%
Successor [Member] | Cleco Holdings [Member] | Line of Credit [Member] | LIBOR [Member]
Line of Credit Facility [Line Items]
Credit facility, Basis Spread on Variable Rate (in hundredths)		1.75%
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member] | Cleco Holdings [Member] | ABR [Member]
Line of Credit Facility [Line Items]
Credit facility, Basis Spread on Variable Rate (in hundredths)	0.75%
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member] | Cleco Holdings [Member] | LIBOR [Member]
Line of Credit Facility [Line Items]
Credit facility, Basis Spread on Variable Rate (in hundredths)	1.75%

Common Stock, Employee Stock Pu

Common Stock, Employee Stock Purchase Plan (Details) - Predecessor [Member] - Employee stock purchase plan [Member]	12 Months Ended
	Dec. 31, 2016shares
Employee Stock Purchase Plan Disclosures [Line Items]
Discount on the fair market value of shares that were purchased as of the last trading day of each calendar quarter (in hundredths)	5.00%
Maximum number of shares of common stock a participant could have purchased per offering period (in shares)	125
Maximum number of shares of common stock that was available to be purchased under the ESPP (in shares)	73,400

Common Stock, Long-Term Incenti

Common Stock, Long-Term Incentive Compensation Plan (Details) - Predecessor [Member] - shares	3 Months Ended	12 Months Ended	72 Months Ended
	Apr. 12, 2016	Dec. 31, 2015	Dec. 31, 2015
2000 Long-Term Incentive Compensation Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares of common stock granted during the year (in shares)			0
2010 Long-Term Incentive Compensation Plan [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Non-vested shares of common stock granted during the year (in shares)	0
Maximum number of shares of common stock that was authorized for issuance under 2010 LTIP (in shares)		2,250,000	2,250,000
Number of shares of common stock granted and immediately vested under the 2010 LTIP (in shares)		9,611

Common Stock, Long-Term Incen76

Common Stock, Long-Term Incentive Compensation Plan, Non-vested Stock and Common Stock Equivalent Units (Details) - Predecessor [Member] - Restricted Stock [Member] - USD ($) $ / shares in Units, $ in Millions	3 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Non-Vested Stock, Weighted Average Grant Date Fair Value [Roll Forward]
Weighted average grant date fair value, non-vested, beginning of period (in dollars per share)	$ 48.11
Weighted average grant date fair value, non-vested, vested (in dollars per share)	46.53
Weighted average grant date fair value, non-vested, forfeited (in dollars per share)	54.64
Weighted average grant date fair value, non-vested, end of period (in dollars per share)	$ 0	$ 48.11
Non-Vested Stock, Activity [Roll Forward]
Shares, non-vested, beginning of period (in shares)	269,988
Shares, vested (in shares)	(217,588)
Shares, forfeited (in shares)	(52,400)
Shares, non-vested, end of period (in shares)	0	269,988
Non-Vested Stock, Fair Value Assumptions [Abstract]
Expected term (in years)		3 years	3 years
Volatility of Cleco stock (in hundredths)		15.80%	17.30%
Correlation between Cleco stock volatility and peer group (in hundredths)		63.10%	66.50%
Expected dividend yield (in hundredths)		2.90%	3.00%
Weighted average fair value (Monte Carlo model) (in dollars per share)		$ 45.60	$ 54.58
Share-based Compensation Arrangement by Share-based Payment Award, Additional General Disclosures [Abstract]
Fair value of shares of non-vested stock vested during period	$ 10.1	$ 3.3	$ 5.6
2010 Long-Term Incentive Compensation Plan [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Additional General Disclosures [Abstract]
Non-vested shares of common stock granted during the year (in shares)	0

Common Stock, Stock-Based Compe

Common Stock, Stock-Based Compensation (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 30, 2016	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Tax benefit				$ 384	$ 770	$ 771
Amount of stock based compensation capitalized in property, plant, and equipment				600	700
Cleco Power [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre-tax compensation expense				$ 997	2,000	2,004
Successor [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Tax benefit			$ 0
Successor [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Pre-tax compensation expense			0
Predecessor [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Tax benefit			1,247		2,351	2,427
Compensation expense, non-forfeitable dividends paid on non-vested stock not expected to vest and stock options		$ 100			100	100
Amount of stock based compensation capitalized in property, plant, and equipment		$ 600			800
Predecessor [Member] | Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Merger expense due to accelerated vesting of LTIP shares	$ 2,300
Pre-tax compensation expense			$ 3,241		$ 6,110	$ 6,308

Common Stock, Common Stock Repu

Common Stock, Common Stock Repurchase Program (Details) - shares	3 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Predecessor [Member] | Cleco Holdings [Member]
Equity, Class of Treasury Stock [Line Items]
Common stock repurchased (in shares)	0	0	250,000

Pension Plan and Employee Ben79

Pension Plan and Employee Benefits, Benefit Obligation, Plan Assets, and Funded Status (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor [Member] | Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation		$ 473,197
Change in benefit obligation [Roll Forward]
Benefit obligation at beginning of year		499,724
Service cost		6,909
Interest cost		15,088
Plan participants' contributions		0
Actuarial (gain) loss		6,242
Expenses paid		(2,025)
Medicare D		0
Benefits paid		(13,153)
Benefit obligation at end of year	$ 499,724	512,785
Change in plan assets [Roll Forward]
Fair value of plan assets at beginning of year		398,515
Actual return on plan assets		20,378
Expenses paid		(2,025)
Benefits paid		(13,153)
Fair value of plan assets at end of year	398,515	403,715
Unfunded status		(109,070)
Successor [Member] | Other Benefits [Member]
Change in benefit obligation [Roll Forward]
Benefit obligation at beginning of year		42,707
Service cost		1,112
Interest cost		1,237
Plan participants' contributions		758
Actuarial (gain) loss		2,292
Expenses paid		0
Medicare D		0
Benefits paid		(3,970)
Benefit obligation at end of year	42,707	44,136
Change in plan assets [Roll Forward]
Expenses paid		0
Benefits paid		(3,970)
Unfunded status		(44,136)
Successor [Member] | SERP Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation		76,194
Change in benefit obligation [Roll Forward]
Benefit obligation at beginning of year		79,555
Service cost		571
Interest cost		2,275
Actuarial (gain) loss		1,152
Plan Amendments		(2,509)
Benefits paid		(2,999)
Curtailments		0
Special/contractual termination benefits		0
Benefit obligation at end of year	79,555	78,045
Change in plan assets [Roll Forward]
Benefits paid		(2,999)
Predecessor [Member] | Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation			$ 440,876
Change in benefit obligation [Roll Forward]
Benefit obligation at beginning of year	480,062	499,724	498,372
Service cost	2,563		10,419	$ 8,050
Interest cost	6,242		20,795	19,851
Plan participants' contributions	0		0
Actuarial (gain) loss	16,857		(30,483)
Expenses paid	(801)		(1,995)
Medicare D	0		0
Benefits paid	(5,199)		(17,046)
Benefit obligation at end of year	499,724		480,062	498,372
Change in plan assets [Roll Forward]
Fair value of plan assets at beginning of year	383,532	398,515	412,803
Actual return on plan assets	20,983		(10,230)
Expenses paid	(801)		(1,995)
Benefits paid	(5,199)		(17,046)
Fair value of plan assets at end of year	398,515		383,532	412,803
Unfunded status	(101,209)		(96,530)
Predecessor [Member] | Other Benefits [Member]
Change in benefit obligation [Roll Forward]
Benefit obligation at beginning of year	43,070	42,707	44,652
Service cost	431		1,635	1,542
Interest cost	476		1,607	1,809
Plan participants' contributions	300		903
Actuarial (gain) loss	0		(1,039)
Expenses paid	0		0
Medicare D	0		48
Benefits paid	(1,570)		(4,736)
Benefit obligation at end of year	42,707		43,070	44,652
Change in plan assets [Roll Forward]
Expenses paid	0		0
Benefits paid	(1,570)		(4,736)
Unfunded status	(42,707)		(43,070)
Predecessor [Member] | SERP Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation			65,840
Change in benefit obligation [Roll Forward]
Benefit obligation at beginning of year	72,315	$ 79,555	73,902
Service cost	702		2,705	2,278
Interest cost	900		3,056	3,028
Actuarial (gain) loss	0		(4,488)
Benefits paid	(1,186)		(2,860)
Curtailments	3,602		0	0
Special/contractual termination benefits	3,222		0	0
Benefit obligation at end of year	79,555		72,315	$ 73,902
Change in plan assets [Roll Forward]
Benefits paid	$ (1,186)		$ (2,860)

Pension Plan and Employee Ben80

Pension Plan and Employee Benefits, Amounts Recognized in Other Comprehensive Income (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015
Successor [Member] | Pension Benefits [Member]
Amounts recognized in other comprehensive income [Abstract]
Net actuarial loss (gain) occurring during period		$ (10,198)
Net actuarial loss amortized during period		8,138
Prior service cost (credit) amortized during period		(51)
Amounts in accumulated other comprehensive income to be recognized in next fiscal year [Abstract]
Future Net actuarial loss (gain)			$ 9,647
Future Prior service cost (credit)			(71)
Amounts in accumulated other comprehensive income [Abstract]
Net actuarial loss (gain)		145,542	145,542
Prior service cost (credit)		(274)	(274)
Successor [Member] | Other Benefits [Member]
Amounts recognized in other comprehensive income [Abstract]
Net actuarial loss (gain) occurring during period		2,292
Net actuarial loss amortized during period		0
Prior service cost (credit) amortized during period		0
Amounts in accumulated other comprehensive income to be recognized in next fiscal year [Abstract]
Future Net actuarial loss (gain)			0
Future Prior service cost (credit)			0
Amounts in accumulated other comprehensive income [Abstract]
Net actuarial loss (gain)		2,292	2,292
Prior service cost (credit)		0	0
Successor [Member] | SERP Benefits [Member]
Amounts recognized in other comprehensive income [Abstract]
Net actuarial loss (gain) occurring during period		(1,345)
Net actuarial loss amortized during period		1,651
Prior service cost (credit) amortized during period		(50)
Amounts in accumulated other comprehensive income to be recognized in next fiscal year [Abstract]
Future Net actuarial loss (gain)			1,634
Future Prior service cost (credit)			(190)
Amounts in accumulated other comprehensive income [Abstract]
Net actuarial loss (gain)		20,999	20,999
Prior service cost (credit)		$ (2,368)	$ (2,368)
Predecessor [Member] | Pension Benefits [Member]
Amounts recognized in other comprehensive income [Abstract]
Net actuarial loss (gain) occurring during period	$ 16,056			$ 3,128
Net actuarial loss amortized during period	2,798			13,828
Prior service cost (credit) amortized during period	(20)			(71)
Amounts in accumulated other comprehensive income [Abstract]
Net actuarial loss (gain)				150,620
Prior service cost (credit)				(345)
Predecessor [Member] | Other Benefits [Member]
Amounts recognized in other comprehensive income [Abstract]
Net actuarial loss (gain) occurring during period	0			(1,039)
Net actuarial loss amortized during period	181			866
Prior service cost (credit) amortized during period	34			119
Amounts in accumulated other comprehensive income [Abstract]
Net actuarial loss (gain)				8,805
Prior service cost (credit)				363
Predecessor [Member] | SERP Benefits [Member]
Amounts recognized in other comprehensive income [Abstract]
Net actuarial loss (gain) occurring during period	0			(4,487)
Net actuarial loss amortized during period	574			2,973
Prior service cost (credit) amortized during period	$ 17			54
Amounts in accumulated other comprehensive income [Abstract]
Net actuarial loss (gain)				23,763
Prior service cost (credit)				$ 120

Pension Plan and Employee Ben81

Pension Plan and Employee Benefits, Components of Periodic Benefit Costs and Weighted-Average Assumptions (Details) - USD ($) $ in Thousands	3 Months Ended	4 Months Ended	5 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Aug. 31, 2016	Dec. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Apr. 13, 2016
Other Benefits [Member] | Cleco Power [Member]
Components of net periodic pension and other benefits costs [Abstract]
Net periodic benefit cost						$ 3,500	$ 3,600	$ 3,600
SERP Benefits [Member] | Cleco Power [Member]
Components of net periodic pension and other benefits costs [Abstract]
Net periodic benefit cost						$ 1,400	2,200	1,700
Predecessor [Member] | Pension Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Service cost	$ 2,563						10,419	8,050
Interest cost	6,242						20,795	19,851
Expected return on plan assets	(6,812)						(23,382)	(24,507)
Transition obligation	0						0	0
Prior period service (credit) cost	(20)						(71)	(71)
Net loss	2,798						13,828	6,743
Net periodic benefit cost	4,771						$ 21,589	$ 10,066
Expected net periodic benefit cost, pension plan	$ 15,900
Weighted-average assumptions used to determine the benefit obligation [Abstract]
Discount rate (in hundredths)	4.62%						4.62%
Rate of compensation increase (in hundredths)							3.08%
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Discount rate (in hundredths)	4.62%						4.21%	5.14%
Expected return on plan assets (in hundredths)	6.21%						6.15%	6.76%
Rate of compensation increase (in hundredths)	3.03%						3.08%	3.17%
Predecessor [Member] | Other Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Service cost	$ 431						$ 1,635	$ 1,542
Interest cost	476						1,607	1,809
Expected return on plan assets	0						0	0
Transition obligation	0						0	16
Prior period service (credit) cost	34						119	119
Net loss	181						866	670
Net periodic benefit cost	$ 1,122						$ 4,227	$ 4,156
Weighted-average assumptions used to determine the benefit obligation [Abstract]
Discount rate (in hundredths)							4.08%
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Discount rate (in hundredths)	4.08%						3.76%	4.46%
Predecessor [Member] | SERP Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Service cost	$ 702						$ 2,705	$ 2,278
Interest cost	900						3,056	3,028
Prior period service (credit) cost	17						54	54
Net loss	574						2,973	1,875
Net Periodic Benefit Cost, excluding Settlements and Curtailments	2,193						8,788	7,235
Curtailments	3,602						0	0
Special/contractual termination benefits	3,222						0	0
Net periodic benefit cost	$ 9,017						$ 8,788	$ 7,235
Weighted-average assumptions used to determine the benefit obligation [Abstract]
Discount rate (in hundredths)	4.60%						4.60%
Rate of compensation increase (in hundredths)							5.00%
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Discount rate (in hundredths)	4.60%						4.20%	5.09%
Rate of compensation increase (in hundredths)	5.00%						5.00%	5.00%
Predecessor [Member] | Other Subsidiaries [Member] | Pension Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Net periodic benefit cost	$ 500
Predecessor [Member] | Other Subsidiaries [Member] | Pension Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Net periodic benefit cost							$ 2,100	$ 1,700
Successor [Member] | Pension Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Service cost				$ 6,909
Interest cost				15,088
Expected return on plan assets				(17,310)
Transition obligation				0
Prior period service (credit) cost				(51)
Net loss				8,138
Net periodic benefit cost				12,774
Expected net periodic benefit cost, pension plan				$ 17,500
Weighted-average assumptions used to determine the benefit obligation [Abstract]
Discount rate (in hundredths)		4.27%		4.27%		4.27%			4.21%
Rate of compensation increase (in hundredths)		3.03%		3.03%		3.03%
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Discount rate (in hundredths)				4.21%
Expected return on plan assets (in hundredths)				6.21%
Rate of compensation increase (in hundredths)				3.03%
Successor [Member] | Other Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Service cost				$ 1,112
Interest cost				1,237
Expected return on plan assets				0
Transition obligation				0
Prior period service (credit) cost				0
Net loss				0
Net periodic benefit cost				$ 2,349
Weighted-average assumptions used to determine the benefit obligation [Abstract]
Discount rate (in hundredths)		3.81%		3.81%		3.81%
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Discount rate (in hundredths)				4.08%
Successor [Member] | SERP Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Service cost				$ 571
Interest cost				2,275
Prior period service (credit) cost				(50)
Net loss				1,651
Net Periodic Benefit Cost, excluding Settlements and Curtailments				4,447
Curtailments				0
Special/contractual termination benefits				0
Net periodic benefit cost				$ 4,447
Weighted-average assumptions used to determine the benefit obligation [Abstract]
Discount rate (in hundredths)		4.22%	3.47%	4.22%		4.22%			4.15%
Rate of compensation increase (in hundredths)		5.00%		5.00%		5.00%
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Discount rate (in hundredths)		3.47%	4.15%
Rate of compensation increase (in hundredths)		5.00%	5.00%
Successor [Member] | Subsequent Event [Member] | Pension Benefits [Member]
Weighted-average assumptions used to determine the net benefit cost (income) for the year ended December 31:
Expected return on plan assets (in hundredths)					6.08%
Increase (Decrease) in Deferred Pension Costs					$ (2,200)
Successor [Member] | Other Subsidiaries [Member] | Pension Benefits [Member]
Components of net periodic pension and other benefits costs [Abstract]
Net periodic benefit cost				$ 1,300

Pension Plan and Employee Ben82

Pension Plan and Employee Benefits, Amounts Recognized in Balance Sheet (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Successor [Member] | SERP Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
SERP Liabilities, Current	$ 4,308
SERP Liabilities, Noncurrent	73,738
Successor [Member] | Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Other Benefits Liability, Current	3,854
Other Benefits Liability, Noncurrent	40,196
Predecessor [Member] | SERP Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
SERP Liabilities, Current		$ 3,238
SERP Liabilities, Noncurrent		69,049
Predecessor [Member] | Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Other Benefits Liability, Current		3,613
Other Benefits Liability, Noncurrent		39,457
Cleco Power [Member] | SERP Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
SERP Liabilities, Current	885	1,000
SERP Liabilities, Noncurrent	15,145	21,321
Cleco Power [Member] | Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Other Benefits Liability, Current	3,345	3,140
Other Benefits Liability, Noncurrent	$ 34,892	$ 34,300

Pension Plan and Employee Ben83

Pension Plan and Employee Benefits, Fair Value of Pension Plan Assets (Details) - Pension Benefits [Member] - USD ($) $ in Thousands	Dec. 31, 2016	Apr. 13, 2016	Apr. 12, 2016	Dec. 31, 2015	Dec. 31, 2014
Predecessor [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				$ 338,128
Investments Measured at Net Asset Value				42,362
Interest Accrual				3,042
Total net assets			$ 398,515	383,532	$ 412,803
Predecessor [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				4,568
Predecessor [Member] | Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				13,816
Predecessor [Member] | Obligations of U.S. Government, U.S. Government Agencies, and state and local governments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				48,792
Predecessor [Member] | Mutual funds, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				47,801
Predecessor [Member] | Mutual funds, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				22,853
Predecessor [Member] | Real estate funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				17,890
Total net assets			17,871	17,890	$ 18,792
Predecessor [Member] | Corporate debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				182,408
Predecessor [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				84,470
Predecessor [Member] | Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 1 [Member] | Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				13,816
Predecessor [Member] | Level 1 [Member] | Obligations of U.S. Government, U.S. Government Agencies, and state and local governments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 1 [Member] | Mutual funds, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				47,801
Predecessor [Member] | Level 1 [Member] | Mutual funds, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				22,853
Predecessor [Member] | Level 1 [Member] | Real estate funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 1 [Member] | Corporate debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				235,768
Predecessor [Member] | Level 2 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				4,568
Predecessor [Member] | Level 2 [Member] | Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 2 [Member] | Obligations of U.S. Government, U.S. Government Agencies, and state and local governments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				48,792
Predecessor [Member] | Level 2 [Member] | Mutual funds, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 2 [Member] | Mutual funds, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 2 [Member] | Real estate funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 2 [Member] | Corporate debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				182,408
Predecessor [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				17,890
Predecessor [Member] | Level 3 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 3 [Member] | Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 3 [Member] | Obligations of U.S. Government, U.S. Government Agencies, and state and local governments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 3 [Member] | Mutual funds, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 3 [Member] | Mutual funds, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				0
Predecessor [Member] | Level 3 [Member] | Real estate funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				17,890
Predecessor [Member] | Level 3 [Member] | Corporate debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets				$ 0
Successor [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 361,852
Investments Measured at Net Asset Value	38,886
Interest Accrual	2,977
Total net assets	403,715		$ 398,515
Successor [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6,817
Successor [Member] | Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	19,311
Successor [Member] | Obligations of U.S. Government, U.S. Government Agencies, and state and local governments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	47,543
Successor [Member] | Mutual funds, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	52,663
Successor [Member] | Mutual funds, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	31,191
Successor [Member] | Real estate funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	18,668
Total net assets	18,668	$ 17,871
Successor [Member] | Corporate debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	185,659
Successor [Member] | Level 1 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	103,165
Successor [Member] | Level 1 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 1 [Member] | Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	19,311
Successor [Member] | Level 1 [Member] | Obligations of U.S. Government, U.S. Government Agencies, and state and local governments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 1 [Member] | Mutual funds, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	52,663
Successor [Member] | Level 1 [Member] | Mutual funds, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	31,191
Successor [Member] | Level 1 [Member] | Real estate funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 1 [Member] | Corporate debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 2 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	240,019
Successor [Member] | Level 2 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	6,817
Successor [Member] | Level 2 [Member] | Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 2 [Member] | Obligations of U.S. Government, U.S. Government Agencies, and state and local governments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	47,543
Successor [Member] | Level 2 [Member] | Mutual funds, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 2 [Member] | Mutual funds, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 2 [Member] | Real estate funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 2 [Member] | Corporate debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	185,659
Successor [Member] | Level 3 [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	18,668
Successor [Member] | Level 3 [Member] | Cash and Cash Equivalents [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 3 [Member] | Common Stock [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 3 [Member] | Obligations of U.S. Government, U.S. Government Agencies, and state and local governments [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 3 [Member] | Mutual funds, Domestic [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 3 [Member] | Mutual funds, International [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	0
Successor [Member] | Level 3 [Member] | Real estate funds [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	18,668
Successor [Member] | Level 3 [Member] | Corporate debt [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair value of plan assets	$ 0

Pension Plan and Employee Ben84

Pension Plan and Employee Benefits, Unobservable Input Reconciliation (Details) - Pension Benefits [Member] - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2015
Predecessor [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation[Roll Forward]
Fair value of plan assets at beginning of year	$ 383,532		$ 412,803
Fair value of plan assets at end of year	398,515		383,532
Predecessor [Member] | Real estate funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation[Roll Forward]
Fair value of plan assets at beginning of year	17,890		18,792
Realized gains	71		9
Unrealized gains (losses)	89		(148)
Purchases	26		679
Sales	(205)		(1,442)
Fair value of plan assets at end of year	17,871		$ 17,890
Successor [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation[Roll Forward]
Fair value of plan assets at end of year	$ 398,515	$ 403,715
Successor [Member] | Real estate funds [Member]
Defined Benefit Plan, Change in Fair Value of Plan Assets, Level 3 Reconciliation[Roll Forward]
Fair value of plan assets at beginning of year		17,871
Realized gains		151
Unrealized gains (losses)		226
Purchases		570
Sales		(151)
Fair value of plan assets at end of year		$ 18,668

Pension Plan and Employee Ben85

Pension Plan and Employee Benefits, Pension Plan Investment Objectives (Details) - Successor [Member] - Pension Benefits [Member]	12 Months Ended
	Dec. 31, 2016
Defined Benefit Plan Disclosure [Line Items]
Maximum notional value of derivative positions of the total pension fund's value	20.00%
Return Seeking [Member]
Investment asset allocation target percentage of total plan assets [Abstract]
Target plan allocations, minimum	35.00%
Target plan allocations	40.00%
Target plan allocations, maximum	45.00%
Domestic equity [Member]
Investment asset allocation target percentage of total plan assets [Abstract]
Target plan allocations	18.00%
International equity [Member]
Investment asset allocation target percentage of total plan assets [Abstract]
Target plan allocations	17.00%
Real estate funds [Member]
Investment asset allocation target percentage of total plan assets [Abstract]
Target plan allocations	5.00%
Liability Hedging [Member]
Investment asset allocation target percentage of total plan assets [Abstract]
Target plan allocations, minimum	55.00%
Target plan allocations	60.00%
Target plan allocations, maximum	65.00%

Pension Plan and Employee Ben86

Pension Plan and Employee Benefits, 401 (K) Plans (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor [Member]
401(k) Plan [Abstract]
401 (k) Plan expense		$ 3,554
Successor [Member] | Other Subsidiaries [Member]
401(k) Plan [Abstract]
401 (k) Plan expense		$ 554
Predecessor [Member]
401(k) Plan [Abstract]
401 (k) Plan expense	$ 1,593		$ 5,029	$ 4,730
Predecessor [Member] | Other Subsidiaries [Member]
401(k) Plan [Abstract]
401 (k) Plan expense	$ 319		$ 944	$ 921

Pension Plan and Employee Ben87

Pension Plan and Employee Benefits, Additional Disclosures (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
SERP Benefits [Member]
Projected benefit payments [Abstract]
2,017		$ 4,399	$ 4,399
2,018		4,444	4,444
2,019		4,483	4,483
2,020		4,558	4,558
2,021		4,578	4,578
Next five years		$ 23,168	$ 23,168
Predecessor [Member] | Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual return on plan assets (in hundredths)				(2.90%)
Expected return on plan assets (in hundredths)	6.21%			6.15%	6.76%
Successor [Member] | Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Actual return on plan assets (in hundredths)			10.90%
Expected return on plan assets (in hundredths)		6.21%
Projected benefit payments [Abstract]
2,017		$ 20,152	$ 20,152
2,018		21,265	21,265
2,019		22,382	22,382
2,020		23,719	23,719
2,021		24,818	24,818
Next five years		141,584	$ 141,584
Successor [Member] | Other Benefits [Member]
Impact of future Medicare subsidies on the components of other benefit costs [Abstract]
Assumed health care cost trend rates for next fiscal year(in hundredths)			5.00%	5.00%
Ultimate health care trend rate (in hundredths)			5.00%
Effect of one-percentage point change in assumed health care cost trend rates [Abstract]
Effect of one-percentage point increase on total of service and interest cost components			$ 19
Effect of one-percentage point decrease on total of service and interest cost components			(22)
Effect of one-percentage point increase on postretirement benefit obligation			238
Effect of one-percentage point decrease on postretirement benefit obligation			(265)
Projected benefit payments [Abstract]
2,017		3,927	3,927
2,018		3,951	3,951
2,019		4,002	4,002
2,020		4,006	4,006
2,021		3,993	3,993
Next five years		$ 18,190	$ 18,190

Income Taxes, Effective Tax Rat

Income Taxes, Effective Tax Rate Reconciliation (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Income tax reconciliation [Abstract]
Income before tax			$ 57,497	$ 220,644	$ 231,290
Statutory rate (in hundredths)			35.00%	35.00%	35.00%
Tax at federal statutory rate			$ 20,124	$ 77,225	$ 80,952
Increase (decrease):
Plant differences, including AFUDC flowthrough			(58)	1,875	462
Amortization of investment tax credits			(494)	(916)	(983)
State income taxes			(2,573)	1,501	351
Settlement with taxing authorities			0	0	(2,320)
Return to accrual adjustment			(2,646)		0
Other			4,016	(391)	(1,488)
Total taxes			$ 18,369	$ 79,294	$ 76,974
Effective Rate (in hundredths)			31.90%	35.90%	33.30%
Successor [Member]
Income tax reconciliation [Abstract]
Income before tax		$ (46,935)
Statutory rate (in hundredths)		35.00%
Tax at federal statutory rate		$ (16,427)
Increase (decrease):
Plant differences, including AFUDC flowthrough		(881)
Amortization of investment tax credits		(371)
State income taxes		(4,725)
Nondeductible merger costs		(844)
Settlement with taxing authorities		0
Return to accrual adjustment		(2,943)
NMTC		(181)
Other		3,550
Total taxes		$ (22,822)
Effective Rate (in hundredths)		48.60%
Predecessor [Member]
Income tax reconciliation [Abstract]
Income before tax	$ (492)			$ 211,373	$ 221,855
Statutory rate (in hundredths)	35.00%			35.00%	35.00%
Tax at federal statutory rate	$ (172)			$ 73,981	$ 77,649
Increase (decrease):
Plant differences, including AFUDC flowthrough	823			1,875	462
Amortization of investment tax credits	(124)			(916)	(983)
State income taxes	(3,078)			1,117	23
Nondeductible merger costs	4,282			0	0
Settlement with taxing authorities	0			0	(9,106)
Return to accrual adjustment	0			0	0
NMTC	(158)			243	(754)
Other	1,895			1,404	(175)
Total taxes	$ 3,468			$ 77,704	$ 67,116
Effective Rate (in hundredths)	(704.90%)			36.80%	30.30%

Income Taxes, Current and Defer

Income Taxes, Current and Deferred Income Tax Expense (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Current and deferred income tax expense [Abstract]
Current federal income tax (benefit) expense			$ (1,211)	$ 33,138	$ (197)
Deferred federal income tax (benefit) expense			22,647	45,572	83,676
Amortization of accumulated deferred investment tax credits			(494)	(916)	(983)
Total federal income tax (benefit) expense			20,942	77,794	82,496
Current state income tax (benefit) expense			(418)	3,397	(4,161)
Deferred state income tax expense (benefit)			(2,155)	(1,897)	(1,361)
Total state income tax expense (benefit)			(2,573)	1,500	(5,522)
Total taxes			18,369	79,294	76,974
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity			2,295	123	(1,321)
Total federal and state income tax expense			20,664	79,417	75,653
Federal [Member] | Cleco Power [Member]
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity			1,976	106	(1,137)
State [Member] | Cleco Power [Member]
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity			$ 319	17	(184)
Predecessor [Member]
Current and deferred income tax expense [Abstract]
Current federal income tax (benefit) expense	$ 1,373			1,284	11,082
Deferred federal income tax (benefit) expense	5,297			76,219	71,061
Amortization of accumulated deferred investment tax credits	(124)			(916)	(983)
Total federal income tax (benefit) expense	6,546			76,587	81,160
Current state income tax (benefit) expense	0			3,233	(6,580)
Deferred state income tax expense (benefit)	(3,078)			(2,116)	(7,464)
Total state income tax expense (benefit)	(3,078)			1,117	(14,044)
Total taxes	3,468			77,704	67,116
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity	(322)			3,802	(4,246)
Total federal and state income tax expense	3,146			81,506	62,870
Predecessor [Member] | Federal [Member]
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity	(277)			3,274	(3,656)
Predecessor [Member] | State [Member]
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity	$ (45)			$ 528	$ (590)
Successor [Member]
Current and deferred income tax expense [Abstract]
Current federal income tax (benefit) expense		$ (1,062)
Deferred federal income tax (benefit) expense		(16,715)
Amortization of accumulated deferred investment tax credits		(371)
Total federal income tax (benefit) expense		(18,148)
Current state income tax (benefit) expense		(337)
Deferred state income tax expense (benefit)		(4,337)
Total state income tax expense (benefit)		(4,674)
Total taxes		(22,822)
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity		17,034
Total federal and state income tax expense		(5,788)
Successor [Member] | Federal [Member]
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity		14,593
Successor [Member] | State [Member]
Items charged or credited directly to shareholders' equity
Income Tax Effects Allocated Directly to Equity		$ 2,441

Income Taxes, Deferred Tax Asse

Income Taxes, Deferred Tax Assets and Liabilities (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Dec. 31, 2015
Cleco Power [Member]
Components of deferred tax assets and liabilities [Abstract]
Depreciation and property basis differences	$ (941,166)	$ (944,675)
Net operating loss carryforward	(362)	18
Fuel costs	(8,802)	(7,833)
Other comprehensive income	8,021	9,878
Regulated operations regulatory liability, net	(91,734)	(90,122)
Postretirement benefits other than pension	1,288	(3,853)
Other	(35,837)	(6,944)
Accumulated deferred federal and state income taxes, net	(1,068,592)	(1,043,531)
Successor [Member]
Components of deferred tax assets and liabilities [Abstract]
Depreciation and property basis differences	(943,552)
Net operating loss carryforward	54,727
NMTC	89,411
Fuel costs	(8,802)
Other comprehensive income	3,399
Regulated operations regulatory liability, net	(91,734)
Postretirement benefits other than pension	22,733
Merger, fair value adjustment	(124,254)
Other	(34,983)
Accumulated deferred federal and state income taxes, net	$ (1,033,055)
Predecessor [Member]
Components of deferred tax assets and liabilities [Abstract]
Depreciation and property basis differences		(948,597)
Net operating loss carryforward		12,092
NMTC		87,544
Fuel costs		(7,833)
Other comprehensive income		15,774
Regulated operations regulatory liability, net		(90,122)
Postretirement benefits other than pension		11,561
Merger, fair value adjustment		0
Other		(5,522)
Accumulated deferred federal and state income taxes, net		$ (925,103)

Income Taxes, Valuation Allowan

Income Taxes, Valuation Allowance (Details) - USD ($)	Dec. 31, 2016	Dec. 31, 2015
Cleco Power [Member]
Valuation Allowance [Line Items]
Tax Credit Carryforward, Valuation Allowance	$ 0
Successor [Member] | NMTC
Valuation Allowance [Line Items]
Deferred tax asset, NMTC carryforwards	97,500,000
Tax Credit Carryforward, Valuation Allowance	$ 0
Predecessor [Member] | NMTC
Valuation Allowance [Line Items]
Deferred tax asset, NMTC carryforwards		$ 96,500,000

Income Taxes, Net Operating Los

Income Taxes, Net Operating Losses & Uncertain Tax Positions (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Net Operating Losses [Abstract]
Unrecognized Tax Benefits, Interest payable	$ 0	$ 0
Customer Surcredits	2,500,000	1,300,000
Unrecognized Tax Benefits, Interest Expense	0	0	$ 0
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Liability for Unrecognized Tax Benefits, Beginning	0	0
Liability for Unrecognized Tax Benefits, Ending	0	0	0
Predecessor [Member]
Net Operating Losses [Abstract]
Unrecognized Tax Benefits, Interest payable		0
Unrecognized Tax Benefits, Interest Expense		0	0
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Liability for Unrecognized Tax Benefits, Beginning	0	0	5,071,000
Reduction for tax positions of current period			0
Additions for tax positions of prior years			0
Reduction for tax positions of prior years			0
Reduction for settlement with tax authority			(5,071,000)
Reduction for lapse of statute of limitations			0
Liability for Unrecognized Tax Benefits, Ending		0	0
Unrecognized Tax Benefits, Income Tax Penalties Expense		$ 0	$ 100,000
Successor [Member]
Operating Loss Carryforwards [Line Items]
Liability for Uncertainty in Income Taxes, Noncurrent	0
Net Operating Losses [Abstract]
Unrecognized Tax Benefits, Interest payable	0
Unrecognized Tax Benefits, Interest Expense	0
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Liability for Unrecognized Tax Benefits, Ending	0
Unrecognized Tax Benefits, Income Tax Penalties Expense	0
Successor [Member] | Federal [Member]
Net Operating Losses [Abstract]
Net operating loss carryforwards	89,900,000
Successor [Member] | State [Member]
Net Operating Losses [Abstract]
Net operating loss carryforwards	$ 201,100,000

Disclosures about Segments (Det

Disclosures about Segments (Details) $ in Thousands	Apr. 12, 2016USD ($)	Dec. 31, 2016USD ($)entity	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Apr. 12, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2016USD ($)entity	Dec. 31, 2016USD ($)entity	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Apr. 13, 2016USD ($)
Segment Reporting Information [Line Items]
Number of transmission interconnection facility subsidiaries | entity		2									2	2
Predecessor [Member]
Revenue
Electric operations					$ 281,154								$ 1,142,389	$ 1,225,960
Tolling operations														0
Other operations					19,080								69,186	67,055
Electric customer credits					(364)								(2,173)	(23,530)
Affiliate revenue					0								0	0
Operating revenue, net	$ 32,903				299,870	$ 266,968	$ 279,403	$ 345,468	$ 289,074	$ 295,457			1,209,402	1,269,485
Depreciation and amortization					44,076								149,579	146,505
Merger transaction and commitment costs					34,912								4,591	17,848
Interest charges					22,123								77,991	73,606
Interest income					265								895	1,768
Federal and state income tax (benefit) expense					3,468								77,704	67,116
Net (loss) income	$ (23,328)				(3,960)	$ 19,368	21,850	$ 54,663	$ 30,234	$ 26,922			133,669	154,739
Additions to property, plant, and equipment					42,392								156,819	207,636
Equity investment in investee							16,822						16,822	14,540
Goodwill							0						0
Total segment assets							4,323,354						4,323,354	4,368,418
Predecessor [Member] | Operating Segments [Member] | Cleco Power [Member]
Revenue
Electric operations					281,154								1,142,389	1,225,960
Tolling operations														0
Other operations					18,493								67,109	64,893
Electric customer credits					(364)								(2,173)	(23,530)
Affiliate revenue					263								1,142	1,326
Operating revenue, net					299,546								1,208,467	1,268,649
Depreciation and amortization					43,698								147,839	144,026
Merger transaction and commitment costs					0								0	0
Interest charges					21,840								76,560	74,673
Interest income					208								725	1,707
Federal and state income tax (benefit) expense					12,993								79,294	76,974
Net (loss) income					21,548								141,350	154,316
Additions to property, plant, and equipment					42,353								156,357	206,607
Equity investment in investee							16,822						16,822	14,532
Total segment assets							4,233,337						4,233,337	4,232,942
Predecessor [Member] | Operating Segments [Member] | Corporate and Other [Member]
Revenue
Electric operations					0								0	0
Tolling operations														5,467
Other operations					587								2,078	2,163
Electric customer credits					0								0	0
Affiliate revenue					15,024								57,323	56,031
Operating revenue, net					15,611								59,401	63,661
Depreciation and amortization					377								1,739	2,479
Merger transaction and commitment costs					34,928								4,592	17,848
Interest charges					295								1,149	(1,538)
Interest income					69								(111)	(410)
Federal and state income tax (benefit) expense					(9,525)								(1,590)	(9,858)
Net (loss) income					(25,508)								(7,681)	424
Additions to property, plant, and equipment					39								462	1,029
Equity investment in investee							0						0	8
Total segment assets							21,471						21,471	248,043
Predecessor [Member] | Intersegment Eliminations [Member]
Revenue
Electric operations					0								0	0
Tolling operations														(5,467)
Other operations					0								(1)	(1)
Electric customer credits					0								0	0
Affiliate revenue					(15,287)								(58,465)	(57,357)
Operating revenue, net					(15,287)								(58,466)	(62,825)
Depreciation and amortization					1								1	0
Merger transaction and commitment costs					(16)								(1)	0
Interest charges					(12)								282	471
Interest income					(12)								281	471
Federal and state income tax (benefit) expense					0								0	0
Net (loss) income					0								0	(1)
Additions to property, plant, and equipment					$ 0								0	0
Equity investment in investee							0						0	0
Total segment assets							$ 68,546						$ 68,546	$ (112,567)
Successor [Member]
Revenue
Electric operations												$ 802,592
Other operations												51,562
Electric customer credits												(1,149)
Affiliate revenue												0
Operating revenue, net		$ 266,642	$ 342,860	$ 243,502								853,005
Depreciation and amortization												109,739
Merger transaction and commitment costs												174,696
Interest charges												89,766
Interest income												840
Federal and state income tax (benefit) expense												(22,822)
Net (loss) income		18,180	$ 39,621	$ (81,914)							$ (24,113)	(24,113)
Additions to property, plant, and equipment												144,444
Equity investment in investee		18,672									18,672	18,672
Goodwill		1,490,797									1,490,797	1,490,797			$ 1,490,797
Total segment assets		6,343,144									6,343,144	6,343,144
Successor [Member] | Operating Segments [Member] | Cleco Power [Member]
Revenue
Electric operations												810,075
Other operations												50,080
Electric customer credits												(1,149)
Affiliate revenue												621
Operating revenue, net												859,627
Depreciation and amortization												102,444
Merger transaction and commitment costs												151,501
Interest charges												54,606
Interest income												652
Federal and state income tax (benefit) expense												5,376
Net (loss) income												17,580
Additions to property, plant, and equipment												143,790
Equity investment in investee		18,672									18,672	18,672
Goodwill		1,490,797									1,490,797	1,490,797
Total segment assets		5,758,245									5,758,245	5,758,245
Successor [Member] | Operating Segments [Member] | Corporate and Other [Member]
Revenue
Electric operations												(7,482)
Other operations												1,482
Electric customer credits												0
Affiliate revenue												35,602
Operating revenue, net												29,602
Depreciation and amortization												7,296
Merger transaction and commitment costs												23,195
Interest charges												35,246
Interest income												275
Federal and state income tax (benefit) expense												(28,198)
Net (loss) income												(41,692)
Additions to property, plant, and equipment												654
Equity investment in investee		0									0	0
Goodwill		0									0	0
Total segment assets		614,959									614,959	614,959
Successor [Member] | Intersegment Eliminations [Member]
Revenue
Electric operations												(1)
Other operations												0
Electric customer credits												0
Affiliate revenue												(36,223)
Operating revenue, net												(36,224)
Depreciation and amortization												(1)
Merger transaction and commitment costs												0
Interest charges												(86)
Interest income												(87)
Federal and state income tax (benefit) expense												0
Net (loss) income												(1)
Additions to property, plant, and equipment												0
Equity investment in investee		0									0	0
Goodwill		0									0	0
Total segment assets		$ (30,060)									$ (30,060)	$ (30,060)

Regulation and Rates (Details)

Regulation and Rates (Details) - USD ($)	Feb. 13, 2017	Sep. 29, 2016	Jun. 30, 2016	Dec. 31, 2015	Nov. 30, 2013	Dec. 31, 2016	Dec. 31, 2016	Oct. 31, 2016	Apr. 07, 2016	Oct. 31, 2015
Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Provision for rate refund				$ 2,696,000		$ 3,974,000	$ 3,974,000
Federal Energy Regulatory Commission [Member] | Transmission return on equity [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Provision for rate refund						3,300,000	$ 3,300,000
Federal Energy Regulatory Commission [Member] | MISO Transmission Rates [Member]
Public Utilities, General Disclosures [Line Items]
Return on equity established by FERC (in hundredths)		10.32%			12.38%
Return on equity recommended by ALJ (in hundredths)			9.70%	10.32%	6.68%
Louisiana Public Service Commission [Member] | FRP extension [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Return on equity established by FERC (in hundredths)							10.00%
Percentage of retail earnings within range to be returned to customers (in hundredths)							60.00%
Return on equity for customer credit, low range (in hundredths)							10.90%
Return on equity for customer credit, high range (in hundredths)							11.75%
Louisiana Public Service Commission [Member] | 2015 FRP Monitoring report [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Provision for rate refund										$ 200,000
Louisiana Public Service Commission [Member] | 2016 FRP Monitoring report [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Provision for rate refund								$ 0
Louisiana Public Service Commission [Member] | 2016 Merger Commitment Monitoring report [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Provision for rate refund								$ 300,000
Maximum [Member] | Louisiana Public Service Commission [Member] | FRP extension [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Return on equity established by FERC (in hundredths)							10.90%
Subsequent Event [Member] | Federal Energy Regulatory Commission [Member] | MISO Transmission Rates [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Refunds submitted to MISO	$ 1,200,000
Merger Commitments, rate credits [Member] | Louisiana Public Service Commission [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									$ 136,000,000
Merger Commitments, rate credits [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									136,000,000
Rate Credits issued to customers						121,500,000
Merger Commitments, economic development contribution, disbursed over 5 years [Member] | Louisiana Public Service Commission [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									2,500,000
Merger Commitments, economic development contribution, disbursed over 5 years [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									2,500,000
Merger Commitments, economic development contribution [Member] | Louisiana Public Service Commission [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									7,000,000
Merger Commitments, economic development contribution [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									7,000,000
Merger Commitments, charitable contribution, disbursed over 5 years [Member] | Louisiana Public Service Commission [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									6,000,000
Merger Commitments, charitable contribution, disbursed over 5 years [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									6,000,000
Merger Commitments, cost savings [Member] | Louisiana Public Service Commission [Member]
Public Utilities, General Disclosures [Line Items]
Merger Commitments									1,200,000
Merger Commitments, cost savings [Member] | Louisiana Public Service Commission [Member] | Cleco Power [Member]
Public Utilities, General Disclosures [Line Items]
Provision for rate refund						$ 900,000	$ 900,000
Merger Commitments									$ 1,200,000

Variable Interest Entities (Det

Variable Interest Entities (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Summarized financial information [Abstract]
Current assets	$ 886	$ 2,794
Total assets	37,721	33,763
Current liabilities	376	118
Partners' capital	37,345	33,645
Total liabilities and partners' capital	37,721	33,763
Operating revenue	5,459	3,991	$ 2,248
Operating expenses	5,459	3,991	2,248
Income before taxes	0	0	0
Property, plant, and equipment, net [Member]
Summarized financial information [Abstract]
Noncurrent Asset	25,864	23,749
Other Assets [Member]
Summarized financial information [Abstract]
Noncurrent Asset	10,971	7,220
Cleco Power [Member]
Components of equity method investments [Abstract]
Purchase price	12,873	12,873
Cash contributions	6,399	3,949
Dividend received	(600)	0
Total equity investment in investee	18,672	16,822
Cash contributions to Equity method investments	2,450	2,290	$ 0
Summarized financial information [Abstract]
Partners' capital	37,345	33,645
Proceeds from Equity Method Investment, Dividends or Distributions, Return of Capital	$ 600
Cleco Power [Member] | Variable Interest Entity, Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Variable interest entity, ownership percentage (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	16,822
Cleco Power's maximum exposure to loss	$ 18,672	$ 16,822

Operating Leases (Details)

Operating Leases (Details) $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)railcarTowboat	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Expected operating lease payments [Abstract]
Year ending Dec. 31, 2017	$ 6,820
Year ending Dec. 31, 2018	3,252
Year ending Dec. 31, 2019	2,823
Year ending Dec. 31, 2020	2,801
Year ending Dec. 31, 2021	2,396
Thereafter	3,301
Total operating lease payments	21,393
Operating leases, additional disclosures [Abstract]
Lease expenses recognized	9,000	$ 9,400	$ 9,400
Cleco Power [Member]
Expected operating lease payments [Abstract]
Year ending Dec. 31, 2017	6,505
Year ending Dec. 31, 2018	2,939
Year ending Dec. 31, 2019	2,823
Year ending Dec. 31, 2020	2,801
Year ending Dec. 31, 2021	2,396
Thereafter	3,301
Total operating lease payments	$ 20,765
Cleco Power [Member] | Utility System [Member]
Operating leases, additional disclosures [Abstract]
Term of operating lease (in years)	10 years
Cleco Power [Member] | Utility System 2 [Member]
Operating leases, additional disclosures [Abstract]
Term of operating lease (in years)	10 years
Cleco Power [Member] | Utility System 3 [Member]
Operating leases, additional disclosures [Abstract]
Term of operating lease (in years)	27 years
Cleco Power [Member] | Railroad Transportation Equipment [Member]
Operating leases, additional disclosures [Abstract]
Number of railcars | railcar	231
Cleco Power [Member] | Railcars Group 1 [Member]
Operating leases, additional disclosures [Abstract]
Number of railcars | railcar	115
Cleco Power [Member] | Railcars Group 2 [Member]
Operating leases, additional disclosures [Abstract]
Number of railcars | railcar	116
Cleco Power [Member] | Maritime Equipment [Member]
Operating leases, additional disclosures [Abstract]
Number of Towboats | Towboat	3
Cleco Holdings [Member]
Expected operating lease payments [Abstract]
Year ending Dec. 31, 2017	$ 315
Year ending Dec. 31, 2018	313
Year ending Dec. 31, 2019	0
Year ending Dec. 31, 2020	0
Year ending Dec. 31, 2021	0
Thereafter	0
Total operating lease payments	$ 628

Litigation, Other Commitments97

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Litigation (Details)

Feb. 13, 2017USD ($)

Sep. 29, 2016

Jun. 30, 2016

Dec. 31, 2015USD ($)

Sep. 30, 2015USD ($)

Nov. 30, 2014

Nov. 30, 2013

Dec. 31, 2015USD ($)

Dec. 31, 2015USD ($)

Jan. 19, 2017USD ($)

Dec. 31, 2016USD ($)

Dec. 01, 2016USD ($)

Jun. 24, 2016petition

Litigation [Abstract]

Accrual for various litigation matters

$ 4,800,000

Cleco Power [Member]

Litigation [Abstract]

Provision for rate refund

$ 2,696,000

$ 2,696,000

$ 2,696,000

3,974,000

LPSC 2014-2015 Fuel Audit [Member] | Cleco Power [Member]

Litigation [Abstract]

Fuel expenses included in audit

582,600,000

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

Federal Energy Regulatory Commission [Member] | MISO Transmission Rates [Member]

Litigation [Abstract]

Public Utilities, Approved Return on Equity, Percentage

10.32%

12.38%

Public Utilities, Proposed Return on Equity, Percentage

9.70%

10.32%

6.68%

Public Utilities, Requested Rate Increase (Decrease), Percentage

0.50%

Federal Energy Regulatory Commission [Member] | Transmission return on equity [Member] | Cleco Power [Member]

Litigation [Abstract]

Provision for rate refund

$ 3,300,000

Maximum [Member] | LPSC Nov2010-Dec2015 EAC audit [Member] | Cleco Power [Member]

Litigation [Abstract]

Cost disallowance in audit, excluding interest

$ 100,000

Subsequent Event [Member] | LPSC 2014-2015 Fuel Audit [Member] | Cleco Power [Member]

Litigation [Abstract]

Cost disallowance in audit, excluding interest

$ 0

Subsequent Event [Member] | Federal Energy Regulatory Commission [Member] | MISO Transmission Rates [Member] | Cleco Power [Member]

Litigation [Abstract]

Customer Refundable Fees, Refund Payments

$ 1,200,000

Predecessor [Member]

Litigation [Abstract]

Provision for rate refund

$ 2,696,000

$ 2,696,000

$ 2,696,000

Predecessor [Member] | Gulf Coast Spinning start up costs [Member]

Litigation [Abstract]

Allegations by plaintiff, failure to perform

$ 6,500,000

Predecessor [Member] | Gulf Coast Spinning construction of cotton spinning facility [Member]

Litigation [Abstract]

Allegations by plaintiff, failure to perform

$ 60,000,000

Litigation, Other Commitments98

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Off-Balance Sheet Commitments (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Performance Guarantee [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 42.4
Cleco Power [Member] | Guarantee Issued to Entergy Mississippi on behalf of Attala [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	106.5
Guarantor Obligations, Current Carrying Value	0	$ 3.8
Evangeline [Member] | Indemnification Agreement [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	40
Evangeline [Member] | Indemnification Agreement INCLUDING fundamental organizational structure [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	400
Evangeline [Member] | Cleco Power [Member] | Indemnification Agreement [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	40
Evangeline [Member] | Cleco Power [Member] | Indemnification Agreement INCLUDING fundamental organizational structure [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 400

Litigation, Other Commitments99

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Disclosures about Guarantees (Details) - Cleco Power [Member] - Financial Guarantee [Member] - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 106.5
On-balance sheet guarantees, expected termination dates [Abstract]
Guarantor Obligations, Current Carrying Value	$ 0	$ 3.8

Litigation, Other Commitment100

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Long-Term Purchase Obligations (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member] | Purchase of coal, petroleum coke, limestone, entergy capacity and energy delivery facilities [Member]
Payments required under long-term purchase obligations [Abstract]
Payments under long-term purchase obligations	$ 72,900,000	$ 89,700,000	$ 90,400,000
Long-Term Purchase Obligations [Abstract]
2,017	56,482,000
2,018	14,905,000
2,019	3,688,000
Total long-term purchase obligations	75,075,000
Cleco Holdings [Member] | Successor [Member]
Long-Term Purchase Obligations [Abstract]
Total long-term purchase obligations	$ 0

Litigation, Other Commitment101

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, New Markets Tax Credits (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2008
New Markets Tax Credit [Line Items]
Membership interest in U.S Bank New Markets Tax Credit Fund (in hundredths)			99.90%
Equity contributions to be made to the Fund	$ 285,500,000
Net tax benefits to be received from the Fund	303,800,000
Difference between equity contributions and total benefits received will be recognized over the life of the Fund as net tax benefits	$ 18,300,000
Period (in years) over which gross investment amortization expense is recognized	10 years
Remaining period (in years) of recognition of gross investment amortization expense	2 years
Successor [Member]
New Markets Tax Credit [Line Items]
Liability component contained in the net asset	$ 600,000
Tax benefits in excess of capital contributions	17,300,000
Tax benefits not utilized	$ 116,200,000
Predecessor [Member]
New Markets Tax Credit [Line Items]
Liability component contained in the net asset		$ 0

Litigation, Other Commitment102

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Fuel Transportation Agreement and Capital Leases (Details) - Cleco Power [Member] $ in Thousands	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 28, 2012Towboat
Future minimum lease payments under capital leases [Abstract]
2,017	$ 1,800
Capital lease payments/Current liabilities	1,819	$ 2,607
Barges [Member]
Capital Leased Assets [Line Items]
Capital Leased Assets, Number of Units | Towboat			42
Fuel Transportation Agreement [Abstract]
Repayments of Long-term Capital Lease Obligations	3,700	3,700
Analysis of leased property under capital leases by major classes [Abstract]
Barges	11,350	11,350
Less: accumulated amortization	9,729	7,296
Net capital leases	1,621	4,054
Future minimum lease payments under capital leases [Abstract]
2,017	2,480
Less: executory costs	620
Net minimum lease payments	1,860
Less: amount representing interest	41
Present value of net minimum lease payments	1,819
Capital lease payments/Current liabilities	1,819
Operating Leases, Income Statement, Sublease Revenue		$ 500
Maximum [Member] | Barges [Member]
Future minimum lease payments under capital leases [Abstract]
Operating Leases, Income Statement, Sublease Revenue	$ 100

Affiliate Transactions (Details

Affiliate Transactions (Details) - USD ($) $ in Thousands	Apr. 12, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Jun. 30, 2016	Apr. 12, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Affiliate Transaction [Line Items]
Contribution from parent														$ 50,000
Affiliate revenue														884	$ 1,142	$ 1,326
Other income														31	13	73
Total Affiliate Revenue														915	1,155	1,399
Accounts receivable - affiliate		$ 1,406						$ 1,908				$ 1,406	$ 1,406	1,406	1,908
Accounts payable - affiliate		7,190						6,598				7,190	7,190	7,190	6,598
Distributions to parent		25,000	$ 50,000		$ 10,000		$ 25,000	35,000	$ 40,000	$ 35,000	$ 25,000			110,000	135,000	115,000
Principal Owner [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Contribution from parent														50,000
Other income														19	3	30
Accounts receivable - affiliate		3						653				3	3	3	653
Accounts payable - affiliate		119						564				119	119	119	564
Distributions to parent														110,000	135,000	115,000
Non-cash equity contributions from parent															0	138,100
Support Group [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Affiliate revenue														884	1,142	1,322
Other income														0	0	10
Accounts receivable - affiliate		1,402						1,254				1,402	1,402	1,402	1,254
Accounts payable - affiliate		7,071						6,034				7,071	7,071	7,071	6,034
Transfer of pension plan liability and an equal amount of assets														1,771	2,055
Evangeline [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Affiliate revenue														0	0	4
Other income														0	0	9
Diversified Lands [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Other income														0	10	14
Perryville [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Other income														6	0	5
Attala [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Other income														6	0	5
Others [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Accounts receivable - affiliate		1						1				1	1	1	1
Accounts payable - affiliate		0						0				0	0	0	0
Other Operations [Member] | Support Group [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Expenses from transactions with related parties														46,116	53,079	50,801
Maintenance [Member] | Support Group [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Expenses from transactions with related parties														2,255	1,807	2,091
Taxes other than income taxes [Member] | Support Group [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Expenses from transactions with related parties														10	(3)	(9)
Other Expense [Member] | Support Group [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Expenses from transactions with related parties														106	403	339
Power purchased for utility customers [Member] | Evangeline [Member] | Cleco Power [Member]
Affiliate Transaction [Line Items]
Expenses from transactions with related parties														0	0	5,467
Predecessor [Member]
Affiliate Transaction [Line Items]
affiliate balances that were payable to or receivable from its non-consolidated affiliates								0							0
Affiliate revenue						$ 0									0	$ 0
Distributions to parent	$ 0						$ 0
Predecessor [Member] | Cleco Holdings [Member]
Affiliate Transaction [Line Items]
Accounts receivable - affiliate								7,669							7,669
Accounts payable - affiliate								$ 5,389							$ 5,389
Predecessor [Member] | Principal Owner [Member] | Cleco Holdings [Member]
Affiliate Transaction [Line Items]
Accounts payable - affiliate		0										0	0	0
Successor [Member]
Affiliate Transaction [Line Items]
Affiliate revenue													0
Distributions to parent		32,765	$ 28,000	$ 28,000								88,765
Successor [Member] | Cleco Holdings [Member]
Affiliate Transaction [Line Items]
Accounts receivable - affiliate		7,070										7,070	7,070	7,070
Accounts payable - affiliate		14,521										14,521	14,521	14,521
Successor [Member] | Principal Owner [Member] | Cleco Holdings [Member]
Affiliate Transaction [Line Items]
Contribution from parent													100,700
Distributions to parent													88,800
Maximum [Member] | Predecessor [Member] | Principal Owner [Member] | Cleco Holdings [Member]
Affiliate Transaction [Line Items]
Accounts receivable - affiliate		$ 100										$ 100	$ 100	$ 100

Intangible Assets and Goodwi104

Intangible Assets and Goodwill (Details) - USD ($)	Apr. 13, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2008
Successor [Member]
Intangible asset, net [Abstract]
Cleco Katrina/Rita right to bill and collect storm recovery charges		$ 70,594,000	$ 70,594,000
Power supply agreements		86,726,000	86,726,000
Trade name		5,100,000	5,100,000
Gross carrying amount		162,420,000	162,420,000
Accumulated amortization		(19,786,000)	(19,786,000)
Net intangible assets subject to amortization		142,634,000	142,634,000
Expected amortization expense [Abstract]
For the year ending Dec. 31, 2017		28,704,000	28,704,000
For the year ending Dec. 31, 2018		29,564,000	29,564,000
For the year ending Dec. 31, 2019		31,087,000	31,087,000
For the year ending Dec. 31, 2020		9,935,000	9,935,000
For the year ending Dec. 31, 2021		9,935,000	9,935,000
Thereafter		33,409,000	33,409,000
Goodwill	$ 1,490,797,000	1,490,797,000	1,490,797,000
Predecessor [Member]
Intangible asset, net [Abstract]
Cleco Katrina/Rita right to bill and collect storm recovery charges				$ 177,537,000
Power supply agreements				0
Trade name				0
Gross carrying amount				177,537,000
Accumulated amortization				(102,574,000)
Net intangible assets subject to amortization				74,963,000
Expected amortization expense [Abstract]
Goodwill				0
Transmission Service Agreement [Member] | Successor [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Residual value of intangible asset	$ 0
Amortization expense		7,500,000
Trade Names [Member] | Successor [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible asset expected useful life (in years)	20 years
Residual value of intangible asset	$ 0
Amortization expense		200,000
Minimum [Member] | Transmission Service Agreement [Member] | Successor [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible asset expected useful life (in years)	2 years
Maximum [Member] | Transmission Service Agreement [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible asset expected useful life (in years)	19 years
Cleco Power [Member]
Intangible asset, net [Abstract]
Cleco Katrina/Rita right to bill and collect storm recovery charges		177,537,000	177,537,000	177,537,000
Accumulated amortization		(119,064,000)	(119,064,000)	(102,574,000)
Net intangible assets subject to amortization		58,473,000	58,473,000	74,963,000
Expected amortization expense [Abstract]
For the year ending Dec. 31, 2017		18,009,000	18,009,000
For the year ending Dec. 31, 2018		19,312,000	19,312,000
For the year ending Dec. 31, 2019		$ 21,152,000	21,152,000
Other Subsidiaries [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Amortization expense			$ 16,500,000	$ 15,700,000	$ 15,400,000
Other Subsidiaries [Member] | Right to bill and collect storm recovery charges from customers [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Acquired intangible asset						$ 177,500,000
Residual value of intangible asset						0
Intangible asset, net [Abstract]
Accumulated amortization	$ 0
Other Subsidiaries [Member] | Contractual Rights [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Acquired intangible asset						176,000,000
Other Subsidiaries [Member] | Financing costs [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Acquired intangible asset						$ 1,500,000
Other Subsidiaries [Member] | Minimum [Member] | Right to bill and collect storm recovery charges from customers [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible asset expected useful life (in years)						12 years
Other Subsidiaries [Member] | Maximum [Member] | Right to bill and collect storm recovery charges from customers [Member]
Acquired Finite-Lived Intangible Assets [Line Items]
Intangible asset expected useful life (in years)						15 years

Coughlin Transfer (Details)

Coughlin Transfer (Details) - Cleco Power [Member] $ in Thousands	1 Months Ended
	Oct. 31, 2012MW	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Mar. 31, 2014USD ($)
Related Party [Line Items]
Long-term Request for Proposal of Electric Power to meet long-term capacity (MW) | MW	800
Net book value		$ 3,172,324	$ 3,120,400
Transfer of Coughlin from affiliate [Member] | Evangeline [Member]
Related Party [Line Items]
Net book value				$ 176,000

Accumulated Other Comprehens106

Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended		12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Apr. 13, 2016	Dec. 31, 2013
Cleco Power [Member]
Accumulated Other Comprehensive Loss [Line Items]
Limited Liability Company (LLC) Members' Equity, Including Portion Attributable to Noncontrolling Interest		$ 1,535,202	$ 1,535,202	$ 1,535,202	$ 1,552,404	$ 1,545,858		$ 1,370,573
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Net current-period other comprehensive income (loss)				3,670	196	(2,111)
Postretirement Benefit Net (Loss) Gain [Member] | Cleco Power [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balances. Beginning	$ (11,364)			(11,364)	(11,349)	(9,026)
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Postretirement benefit adjustments during the period				3,913	(1,232)	(3,344)
Amounts reclassified from accumulated other comprehensive income, net of tax				(454)	1,217	1,021
Net current-period other comprehensive income (loss)				3,459	(15)	(2,323)
Balances, Ending		(7,905)	(7,905)	(7,905)	(11,364)	(11,349)
Net Gain (Loss) on Cash Flow Hedges [Member] | Cleco Power [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balances. Beginning	(5,728)			(5,728)	(5,939)	(6,151)
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Net current-period other comprehensive income (loss)				211	211	212
Balances, Ending		(5,517)	(5,517)	(5,517)	(5,728)	(5,939)
AOCI [Member] | Cleco Power [Member]
Accumulated Other Comprehensive Loss [Line Items]
Limited Liability Company (LLC) Members' Equity, Including Portion Attributable to Noncontrolling Interest		(13,422)	(13,422)	(13,422)	(17,092)	(17,288)		$ (15,177)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balances. Beginning	(17,092)			(17,092)	(17,288)	(15,177)
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Postretirement benefit adjustments during the period				3,913	(1,232)	(3,344)
Amounts reclassified from accumulated other comprehensive income, net of tax				(454)	1,217	1,021
Net current-period other comprehensive income (loss)				3,670	196	(2,111)
Balances, Ending		(13,422)	(13,422)	(13,422)	(17,092)	(17,288)
Interest charges | Net Gain (Loss) on Cash Flow Hedges [Member] | Cleco Power [Member]
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax				211	211	212
Interest charges | AOCI [Member] | Cleco Power [Member]
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax				211	211	212
Predecessor [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balances. Beginning	1,674,841		1,646,061	1,674,841	1,627,270	1,586,197
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Net current-period other comprehensive income (loss)	647				6,080	(6,789)
Balances, Ending	1,646,061				1,674,841	1,627,270
Predecessor [Member] | Postretirement Benefit Net (Loss) Gain [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balances. Beginning	(20,857)		(20,270)	(20,857)	(26,726)	(19,725)
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Postretirement benefit adjustments during the period					2,790	(9,022)
Amounts reclassified from accumulated other comprehensive income, net of tax	587				3,079	2,021
Net current-period other comprehensive income (loss)	587				5,869	(7,001)
Balances, Ending	(20,270)				(20,857)	(26,726)
Predecessor [Member] | Net Gain (Loss) on Cash Flow Hedges [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balances. Beginning	(5,728)		(5,668)	(5,728)	(5,939)	(6,151)
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax	60				211	212
Net current-period other comprehensive income (loss)	60				211	212
Balances, Ending	(5,668)				(5,728)	(5,939)
Predecessor [Member] | AOCI [Member]
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balances. Beginning	(26,585)		(25,938)	(26,585)	(32,665)	(25,876)
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Postretirement benefit adjustments during the period					2,790	(9,022)
Amounts reclassified from accumulated other comprehensive income, net of tax	587				3,079	2,021
Net current-period other comprehensive income (loss)	647				6,080	(6,789)
Balances, Ending	(25,938)				(26,585)	(32,665)
Predecessor [Member] | Interest charges | AOCI [Member]
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Amounts reclassified from accumulated other comprehensive income, net of tax	$ 60				$ 211	$ 212
Successor [Member]
Accumulated Other Comprehensive Loss [Line Items]
Limited Liability Company (LLC) Members' Equity, Including Portion Attributable to Noncontrolling Interest		2,046,763	2,046,763	2,046,763			$ 2,158,141
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Net current-period other comprehensive income (loss)		1,500	1,500
Successor [Member] | Postretirement Benefit Net (Loss) Gain [Member]
Accumulated Other Comprehensive Loss [Line Items]
Limited Liability Company (LLC) Members' Equity, Including Portion Attributable to Noncontrolling Interest							0
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Postretirement benefit adjustments during the period		2,304
Amounts reclassified from accumulated other comprehensive income, net of tax		(804)
Net current-period other comprehensive income (loss)			1,500
Balances, Ending		1,500	1,500	1,500
Successor [Member] | Net Gain (Loss) on Cash Flow Hedges [Member]
Accumulated Other Comprehensive Loss [Line Items]
Limited Liability Company (LLC) Members' Equity, Including Portion Attributable to Noncontrolling Interest							0
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Net current-period other comprehensive income (loss)			0
Balances, Ending		0	0	0
Successor [Member] | AOCI [Member]
Accumulated Other Comprehensive Loss [Line Items]
Limited Liability Company (LLC) Members' Equity, Including Portion Attributable to Noncontrolling Interest		1,500	1,500	1,500			$ 0
Other Comprehensive Income (Loss) Net of Tax, Period Change [Abstract]
Postretirement benefit adjustments during the period		2,304
Amounts reclassified from accumulated other comprehensive income, net of tax		(804)
Net current-period other comprehensive income (loss)		1,500	1,500
Balances, Ending		$ 1,500	$ 1,500	$ 1,500

Miscellaneous Financial Info107

Miscellaneous Financial Information (Unaudited) (Details) - USD ($) $ in Thousands	Apr. 12, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Jun. 30, 2016	Apr. 12, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member]
Quarterly Information [Line Items]
Operating revenue, net		$ 269,017	$ 345,131		$ 278,343		$ 266,682	$ 279,122	$ 345,189	$ 288,885	$ 295,271			$ 1,159,173	$ 1,208,467	$ 1,268,649
Operating income (loss)		59,156	99,420		(81,841)		52,265	54,321	103,966	70,243	65,670			129,000	294,201	299,715
Net (loss) income		26,906	52,572		(61,229)		20,879	22,270	58,661	31,813	28,605			39,128	141,350	154,316
Contributions from member/parent		0	0		50,000		0									138,080
Distributions to member/parent		25,000	50,000		$ 10,000		25,000	35,000	40,000	35,000	25,000			$ 110,000	135,000	115,000
Predecessor [Member]
Quarterly Information [Line Items]
Operating revenue, net	$ 32,903					$ 299,870	266,968	279,403	345,468	289,074	295,457				1,209,402	1,269,485
Operating income (loss)	(29,832)					20,363	50,192	52,162	102,572	69,884	62,722				287,339	286,032
Net (loss) income	(23,328)					$ (3,960)	19,368	$ 21,850	$ 54,663	$ 30,234	$ 26,922				$ 133,669	$ 154,739
Contributions from member/parent	0						0
Distributions to member/parent	$ 0						$ 0
Successor [Member]
Quarterly Information [Line Items]
Operating revenue, net		266,642	342,860	$ 243,502									$ 853,005
Operating income (loss)		53,299	93,143	(110,148)									36,291
Net (loss) income		18,180	39,621	(81,914)								$ (24,113)	$ (24,113)
Contributions from member/parent		0	0	100,720
Distributions to member/parent		$ 32,765	$ 28,000	$ 28,000								$ 88,765

Schedule I Financial Stateme108

Schedule I Financial Statements of Cleco Corporation, Condensed Statements of Income (Details) - USD ($) $ in Thousands	Apr. 12, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Apr. 12, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor [Member]
Operating expenses [Abstract]
Merger transaction costs												$ 174,696
Total operating expenses												816,714
Operating income (loss)		$ 53,299	$ 93,143	$ (110,148)								36,291
Other income												3,350
Other expense												(1,385)
(Loss) income before income taxes												(46,935)
Federal and state income tax benefit												(22,822)
Net (loss) income		$ 18,180	$ 39,621	$ (81,914)							$ (24,113)	(24,113)
Successor [Member] | Cleco Holdings [Member]
Operating expenses [Abstract]
Administrative and general												375
Merger transaction costs												23,211
Other operating expense												(382)
Total operating expenses												23,204
Operating income (loss)												(23,204)
Equity income from subsidiaries, net of tax												9,357
Interest, net												(35,151)
Other income												1,948
Other expense												0
(Loss) income before income taxes												(47,050)
Federal and state income tax benefit												(22,937)
Net (loss) income												$ (24,113)
Predecessor [Member]
Operating expenses [Abstract]
Merger transaction costs					$ 34,912								$ 4,591	$ 17,848
Total operating expenses					279,507								922,063	983,453
Operating income (loss)	$ (29,832)				20,363	$ 50,192	$ 52,162	$ 102,572	$ 69,884	$ 62,722			287,339	286,032
Other income					870								1,443	4,790
Other expense					(590)								(3,376)	(2,509)
(Loss) income before income taxes					(492)								211,373	221,855
Federal and state income tax benefit					3,468								77,704	67,116
Net (loss) income	$ (23,328)				(3,960)	$ 19,368	$ 21,850	$ 54,663	$ 30,234	$ 26,922			133,669	154,739
Predecessor [Member] | Cleco Holdings [Member]
Operating expenses [Abstract]
Administrative and general					319								1,891	1,534
Merger transaction costs					34,912								4,591	17,848
Other operating expense					624								490	178
Total operating expenses					35,855								6,972	19,560
Operating income (loss)					(35,855)								(6,972)	(19,560)
Equity income from subsidiaries, net of tax					21,789								141,636	162,331
Interest, net					(286)								(1,731)	(303)
Other income					702								17	2,457
Other expense					0								(1,142)	(158)
(Loss) income before income taxes					(13,650)								131,808	144,767
Federal and state income tax benefit					(9,690)								(1,861)	(9,972)
Net (loss) income					$ (3,960)								$ 133,669	$ 154,739

Schedule I Financial Stateme109

Schedule I Financial Statements of Cleco Corporation, Condensed Statements of Comprehensive Income (Details) - USD ($) $ in Thousands	Apr. 12, 2016	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Apr. 12, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor [Member]
Condensed Statements of Comprehensive Income [Abstract]
Net (loss) income		$ 18,180	$ 39,621	$ (81,914)							$ (24,113)	$ (24,113)
Other comprehensive income (loss), net of tax:
Postretirement benefits gain (loss), net of tax												1,500
Net gain on cash flow hedges, net of tax												0
Total other comprehensive income (loss), net of tax											$ 1,500	1,500
Comprehensive income, net of tax												(22,613)
Successor [Member] | Cleco Holdings [Member]
Condensed Statements of Comprehensive Income [Abstract]
Net (loss) income												(24,113)
Other comprehensive income (loss), net of tax:
Postretirement benefits gain (loss), net of tax												1,500
Net gain on cash flow hedges, net of tax												0
Total other comprehensive income (loss), net of tax												1,500
Comprehensive income, net of tax												$ (22,613)
Predecessor [Member]
Condensed Statements of Comprehensive Income [Abstract]
Net (loss) income	$ (23,328)				$ (3,960)	$ 19,368	$ 21,850	$ 54,663	$ 30,234	$ 26,922			$ 133,669	$ 154,739
Other comprehensive income (loss), net of tax:
Postretirement benefits gain (loss), net of tax					587								5,869	(7,001)
Net gain on cash flow hedges, net of tax					60								211	212
Total other comprehensive income (loss), net of tax					647								6,080	(6,789)
Comprehensive income, net of tax					(3,313)								139,749	147,950
Predecessor [Member] | Cleco Holdings [Member]
Condensed Statements of Comprehensive Income [Abstract]
Net (loss) income					(3,960)								133,669	154,739
Other comprehensive income (loss), net of tax:
Postretirement benefits gain (loss), net of tax					587								5,869	(7,001)
Net gain on cash flow hedges, net of tax					60								211	212
Total other comprehensive income (loss), net of tax					647								6,080	(6,789)
Comprehensive income, net of tax					$ (3,313)								$ 139,749	$ 147,950

Schedule I Financial Stateme110

Schedule I Financial Statements of Cleco Corporation, Condensed Statements of Comprehensive Income Parenthetical (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor [Member]
Condensed Financial Statements, Captions [Line Items]
Net tax expense (benefit) on post-retirement benefits		$ 938
Net tax expense on cash flow hedges		0
Successor [Member] | Cleco Holdings [Member]
Condensed Financial Statements, Captions [Line Items]
Net tax expense (benefit) on post-retirement benefits		938
Net tax expense on cash flow hedges		$ 0
Predecessor [Member]
Condensed Financial Statements, Captions [Line Items]
Net tax expense (benefit) on post-retirement benefits	$ 367		$ 3,670	$ (4,378)
Net tax expense on cash flow hedges	37		132	132
Predecessor [Member] | Cleco Holdings [Member]
Condensed Financial Statements, Captions [Line Items]
Net tax expense (benefit) on post-retirement benefits	367		3,670	(4,378)
Net tax expense on cash flow hedges	$ 37		$ 132	$ 132

Schedule I Financial Stateme111

Schedule I Financial Statements of Cleco Corporation, Condensed Balance Sheets (Details) - USD ($) $ in Thousands	Dec. 31, 2016	Apr. 12, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Successor [Member]
Current Assets [Abstract]
Cash and cash equivalents	$ 23,077	$ 120,330
Other accounts receivable	19,778
Cash surrender value of trust-owned life insurance policies	77,225
Prepayments	7,813
Other current assets	1,315
Total current assets	427,042
Equity investment in investee	18,672
Tax credit fund investment, net	11,888
Other deferred charges	39,115
Total assets	6,343,144
Current Liabilities [Abstract]
Accounts payable	112,087
Taxes payable	3,942
Other current liabilities	14,850
Total current liabilities	252,176
Postretirement benefit obligations	223,003
Other deferred credits	29,440
Total liabilities	4,296,381
Commitments and Contingencies (Note 5)
Shareholders’ Equity [Abstract]
Members' Capital	2,069,376
(Accumulated deficit)/Retained earnings	(24,113)
Accumulated other comprehensive income (loss)	1,500
Members' Equity	2,046,763
Total liabilities and member’s equity/shareholders’ equity	6,343,144
Successor [Member] | Cleco Holdings [Member]
Current Assets [Abstract]
Cash and cash equivalents	1,377	6,037
Accounts receivable - affiliate	7,070
Other accounts receivable	395
Taxes receivable, net	0
Cash surrender value of trust-owned life insurance policies	57,207
Total current assets	66,049
Equity investment in investee	3,223,920
Tax credit fund investment, net	11,888
Accumulated deferred federal and state income taxes, net	140,577
Other deferred charges	1,351
Total assets	3,443,785
Current Liabilities [Abstract]
Accounts payable	3,424
Accounts payable - affiliate	14,521
Taxes payable	13,998
Other current liabilities	19,566
Total current liabilities	51,509
Postretirement benefit obligations	4,280
Other deferred credits	1,100
Long-term debt	1,340,133
Total liabilities	1,397,022
Commitments and Contingencies (Note 5)
Shareholders’ Equity [Abstract]
Members' Capital	2,069,376
(Accumulated deficit)/Retained earnings	(24,113)
Accumulated other comprehensive income (loss)	1,500
Members' Equity	2,046,763
Total liabilities and member’s equity/shareholders’ equity	$ 3,443,785
Predecessor [Member]
Current Assets [Abstract]
Cash and cash equivalents		120,330	$ 68,246	$ 44,423	$ 28,656
Other accounts receivable			27,677
Cash surrender value of trust-owned life insurance policies			73,823
Prepayments			7,883
Other current assets			448
Total current assets			448,859
Equity investment in investee			16,822	14,540
Tax credit fund investment, net			13,741
Other deferred charges			21,575
Total assets			4,323,354	4,368,418
Current Liabilities [Abstract]
Accounts payable			93,822
Taxes payable			2,573
Other current liabilities			14,277
Total current liabilities			206,579
Postretirement benefit obligations			205,036
Other deferred credits			24,670
Total liabilities			2,648,513
Commitments and Contingencies (Note 5)
Shareholders’ Equity [Abstract]
Members' Capital			456,412
(Accumulated deficit)/Retained earnings			1,245,014
Accumulated other comprehensive income (loss)			(26,585)
Members' Equity			1,674,841
Total member’s equity/common shareholders’ equity		1,646,061	1,674,841	1,627,270	1,586,197
Total liabilities and member’s equity/shareholders’ equity			4,323,354
Predecessor [Member] | Cleco Holdings [Member]
Current Assets [Abstract]
Cash and cash equivalents		$ 6,037	2,236	$ 5,069	$ 7,375
Accounts receivable - affiliate			7,669
Other accounts receivable			0
Taxes receivable, net			14,746
Cash surrender value of trust-owned life insurance policies			53,821
Total current assets			78,472
Equity investment in investee			1,516,310
Tax credit fund investment, net			13,741
Accumulated deferred federal and state income taxes, net			123,690
Other deferred charges			0
Total assets			1,732,213
Current Liabilities [Abstract]
Accounts payable			908
Accounts payable - affiliate			5,389
Taxes payable			0
Other current liabilities			10,975
Total current liabilities			17,272
Postretirement benefit obligations			5,848
Other deferred credits			587
Long-term debt			33,665
Total liabilities			57,372
Commitments and Contingencies (Note 5)
Shareholders’ Equity [Abstract]
Members' Capital			456,412
(Accumulated deficit)/Retained earnings			1,245,014
Accumulated other comprehensive income (loss)			(26,585)
Members' Equity			1,674,841
Total liabilities and member’s equity/shareholders’ equity			$ 1,732,213

Schedule I Financial Stateme112

Schedule I Financial Statements of Cleco Corporation, Condensed Balance Sheet Parentheticals (Details) - Predecessor [Member] - USD ($) $ / shares in Units, $ in Millions	Apr. 12, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Financial Statements, Captions [Line Items]
Common stock, par value (in dollars per share)		$ 1
Common stock, authorized (in shares)		100,000,000
Common stock, issued (in shares)		61,058,918
Common stock, outstanding (in shares)		60,482,468
Treasury stock (in shares)		576,450
Premium on common stock	$ 414.6	$ 418.5	$ 415.5	$ 422.6
Common Stock, Value, Issued	61.1	61.1	61.1	61
Treasury Stock, Value	$ 20.5	$ 23.2	$ 25.3	$ 20.6
Cleco Holdings [Member]
Condensed Financial Statements, Captions [Line Items]
Common stock, par value (in dollars per share)		$ 1
Common stock, authorized (in shares)		100,000,000
Common stock, issued (in shares)		61,058,918
Common stock, outstanding (in shares)		60,482,468
Treasury stock (in shares)		576,450
Premium on common stock		$ 0
Common Stock, Value, Issued		0
Treasury Stock, Value		$ 0

Schedule I Financial Stateme113

Schedule I Financial Statements of Cleco Corporation, Condensed Statements of Cash Flows (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor [Member]
Operating Activities [Abstract]
Net cash provided by operating activities		$ 51,322
Investing Activities [Abstract]
Contributions to tax credit fund		0
Return of equity investment in tax credit fund		901
Premiums paid on trust-owned life insurance		0
Net cash (used in) provided by investing activities		(161,145)
Financing Activities [Abstract]
Draws on credit facility		15,000
Payments on credit facility		(15,000)
Issuance of long-term debt		1,680,000
Repayment of long-term debt		(1,668,268)
Payments of financing costs		(8,655)
Repurchase of common stock		0
Dividends paid on common stock		(572)
Contribution from member		100,720
Distributions to member		(88,765)
Other financing		(1,890)
Net cash provided by (used in) financing activities		12,570
Net increase (decrease) in cash and cash equivalents		(97,253)
Cash and cash equivalents at beginning of period		120,330
Cash and cash equivalents at end of period	$ 120,330	23,077	$ 23,077
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized		116,496
Income taxes paid, net		4,263
Successor [Member] | Cleco Holdings [Member]
Operating Activities [Abstract]
Net cash provided by operating activities		36,811
Investing Activities [Abstract]
Contributions to tax credit fund		0
Return of equity investment in tax credit fund		901
Contribution to subsidiary		(50,000)
Premiums paid on trust-owned life insurance		0
Net cash (used in) provided by investing activities		(49,099)
Financing Activities [Abstract]
Draws on credit facility		0
Payments on credit facility		0
Issuance of long-term debt		1,350,000
Repayment of long-term debt		(1,350,000)
Payments of financing costs		(3,755)
Repurchase of common stock		0
Dividends paid on common stock		(572)
Contribution from member		100,720
Distributions to member		(88,765)
Other financing		0
Net cash provided by (used in) financing activities		7,628
Net increase (decrease) in cash and cash equivalents		(4,660)
Cash and cash equivalents at beginning of period		6,037
Cash and cash equivalents at end of period	6,037	1,377	1,377
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized		26,264
Income taxes paid, net		4,263
Supplementary non-cash investing and financing activities [Abstract]
Non-cash contribution to subsidiary, net of tax		0
Non-cash distribution from subsidiary, net of tax		0
Predecessor [Member]
Operating Activities [Abstract]
Net cash provided by operating activities	129,780			$ 361,022	$ 335,169
Investing Activities [Abstract]
Contributions to tax credit fund	0			(9,966)	(55,315)
Return of equity investment in tax credit fund	476			2,128	2,579
Premiums paid on trust-owned life insurance	0			(3,607)	(2,831)
Net cash (used in) provided by investing activities	(36,811)			(167,951)	(246,514)
Financing Activities [Abstract]
Draws on credit facility	3,000			120,000	254,000
Payments on credit facility	(10,000)			(163,000)	(202,000)
Issuance of long-term debt	0			75,000	0
Repayment of long-term debt	(8,546)			(100,824)	(14,876)
Payments of financing costs	(43)			(693)	(71)
Repurchase of common stock	0			0	(12,449)
Dividends paid on common stock	(24,579)			(97,283)	(95,044)
Contribution from member	0			0	0
Distributions to member	0			0	0
Other financing	(717)			(2,448)	(2,448)
Net cash provided by (used in) financing activities	(40,885)			(169,248)	(72,888)
Net increase (decrease) in cash and cash equivalents	52,084			23,823	15,767
Cash and cash equivalents at beginning of period	68,246	120,330	68,246	44,423	28,656
Cash and cash equivalents at end of period	120,330			68,246	44,423
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized	2,478			74,349	74,515
Income taxes paid, net	(481)			1,434	15,286
Predecessor [Member] | Cleco Holdings [Member]
Operating Activities [Abstract]
Net cash provided by operating activities	34,904			128,909	108,754
Investing Activities [Abstract]
Contributions to tax credit fund	0			(9,966)	(55,315)
Return of equity investment in tax credit fund	476			2,128	2,579
Contribution to subsidiary	0			0	0
Premiums paid on trust-owned life insurance	0			(3,607)	(2,831)
Net cash (used in) provided by investing activities	476			(11,445)	(55,567)
Financing Activities [Abstract]
Draws on credit facility	3,000			57,000	97,000
Payments on credit facility	(10,000)			(80,000)	(45,000)
Issuance of long-term debt	0
Repayment of long-term debt	0
Payments of financing costs	0
Repurchase of common stock	0			0	(12,449)
Dividends paid on common stock	(24,579)			(97,283)	(95,044)
Contribution from member	0
Distributions to member	0
Other financing	0			(14)	0
Net cash provided by (used in) financing activities	(31,579)			(120,297)	(55,493)
Net increase (decrease) in cash and cash equivalents	3,801			(2,833)	(2,306)
Cash and cash equivalents at beginning of period	2,236	$ 6,037	$ 2,236	5,069	7,375
Cash and cash equivalents at end of period	6,037			2,236	5,069
Supplementary cash flow information [Abstract]
Interest paid, net of amount capitalized	126			130	189
Income taxes paid, net	1			1,464	15,013
Supplementary non-cash investing and financing activities [Abstract]
Non-cash contribution to subsidiary, net of tax	0			0	142,880
Non-cash distribution from subsidiary, net of tax	$ 0			$ 33,661	$ 138,080

Schedule I Financial Stateme114

Schedule I Financial Statements of Cleco Corporation, Summary of Significant Accounting Policies (Details) - Cleco Holdings [Member] $ in Millions	Dec. 31, 2016USD ($)
Summary of Significant Accounting Policies [Abstract]
Percent of restricted consolidated net assets of consolidated subsidiaries exceeding total consolidated net assets (in hundredths)	25.00%
Successor [Member]
Summary of Significant Accounting Policies [Abstract]
Restricted net assets of consolidated subsidiaries	$ 1,087
Percent of restricted consolidated net assets of consolidated subsidiaries exceeding total consolidated net assets (in hundredths)	25.00%

Schedule I Financial Stateme115

Schedule I Financial Statements of Cleco Corporation, Business Combinations (Details) - Successor [Member] - Cleco Holdings [Member]	Apr. 13, 2016$ / shares
Business Acquisition [Line Items]
Common stock, par value (in dollars per share)	$ 1
Share price at the time of the Merger (in dollars per share)	$ 55.37

Schedule I Financial Stateme116

Schedule I Financial Statements of Cleco Corporation, Debt (Details) - USD ($)	Jun. 28, 2016	Apr. 13, 2016	Dec. 31, 2016	May 24, 2016	May 17, 2016	Dec. 31, 2015
Predecessor [Member]
Debt [Abstract]
Short-term debt outstanding						$ 0
Long-term Debt and Capital Lease Obligations, Current						19,421,000
Debt Instrument, Fee Amount						9,900,000
Predecessor [Member] | Cleco Holdings [Member]
Debt [Abstract]
Short-term debt outstanding						0
Maximum borrowing capacity						250,000,000
Long-term Line of Credit						34,000,000
Debt Instrument, Fee Amount						$ 336,000
Successor [Member]
Debt [Abstract]
Short-term debt outstanding			$ 0
Long-term Debt and Capital Lease Obligations, Including Current Maturities			2,760,000,000
Long-term Debt and Capital Lease Obligations, Current			19,715,000
Maximum borrowing capacity			400,000,000
2,017			17,896,000
2,018			19,193,000
2,019			20,571,000
2,020			11,055,000
2,021			300,000,000
Thereafter			2,250,000,000
Debt Instrument, Fee Amount			11,700,000
Successor [Member] | Cleco Holdings [Member]
Debt [Abstract]
Short-term debt outstanding			0
Long-term Debt and Capital Lease Obligations, Including Current Maturities			1,340,000,000
Long-term Debt and Capital Lease Obligations, Current			0
Maximum borrowing capacity		$ 100,000,000	$ 100,000,000
Commitment fees (in hundredths)			0.275%
Long-term Line of Credit			$ 0
2,017			0
2,018			0
2,019			0
2,020			0
2,021			300,000,000
Thereafter			1,050,000,000
Debt Instrument, Fee Amount			$ 2,261,000
Successor [Member] | Cleco Holdings [Member] | Line of Credit [Member] | LIBOR [Member]
Debt [Abstract]
Debt Instrument, Basis Spread on Variable Rate			1.75%
Successor [Member] | Cleco Holdings [Member] | Line of Credit [Member] | ABR [Member]
Debt [Abstract]
Debt Instrument, Basis Spread on Variable Rate			0.75%
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2021 [Member] | Cleco Holdings [Member]
Debt [Abstract]
Debt Instrument, Face Amount	$ 300,000,000
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2021 [Member] | Cleco Holdings [Member] | LIBOR [Member]
Debt [Abstract]
Debt Instrument, Basis Spread on Variable Rate	1.625%
Debt Instrument, Interest Rate, Stated Percentage			2.265%
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2021 [Member] | Cleco Holdings [Member] | ABR [Member]
Debt [Abstract]
Debt Instrument, Basis Spread on Variable Rate	0.625%
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member] | Cleco Holdings [Member]
Debt [Abstract]
Debt Instrument, Face Amount		$ 1,350,000,000
Debt Instrument, Term		3 years
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member] | Cleco Holdings [Member] | LIBOR [Member]
Debt [Abstract]
Debt Instrument, Basis Spread on Variable Rate		1.75%
Successor [Member] | Cleco Corporate Holdings debt, variable rate, due 2019 [Member] | Cleco Holdings [Member] | ABR [Member]
Debt [Abstract]
Debt Instrument, Basis Spread on Variable Rate		0.75%
Successor [Member] | Cleco Holdings' senior notes, 3.743%, due 2026 [Member] | Cleco Holdings [Member]
Debt [Abstract]
Debt Instrument, Face Amount					$ 535,000,000
Debt Instrument, Interest Rate, Stated Percentage					3.743%
Successor [Member] | Debt Issuance Cost Amortization [Member] | Cleco Holdings [Member]
Debt [Abstract]
Debt Instrument, Fee Amount		$ 17,700,000
Successor [Member] | Cleco Holdings' senior notes, 4.973%, due 2046 [Member] | Cleco Holdings [Member]
Debt [Abstract]
Debt Instrument, Face Amount					$ 350,000,000
Debt Instrument, Interest Rate, Stated Percentage					4.973%
Successor [Member] | Cleco Holdings' senior notes, 3.250%, due 2023 [Member] | Cleco Holdings [Member]
Debt [Abstract]
Debt Instrument, Face Amount				$ 165,000,000
Debt Instrument, Interest Rate, Stated Percentage				3.25%

Schedule I Financial Stateme117

Schedule I Financial Statements of Cleco Corporation, Cash Distributions and Equity Contributions (Details)	Apr. 12, 2016USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Jun. 30, 2016USD ($)	Apr. 12, 2016USD ($)	Mar. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 30, 2015USD ($)	Jun. 30, 2015USD ($)	Mar. 31, 2015USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Cleco Power [Member]
Distributions from affiliates [Abstract]
Contribution received from member														$ 50,000,000
Distributions to member/parent		$ 25,000,000	$ 50,000,000		$ 10,000,000		$ 25,000,000	$ 35,000,000	$ 40,000,000	$ 35,000,000	$ 25,000,000			110,000,000	$ 135,000,000	$ 115,000,000
Cleco Power [Member] | Cleco Group [Member]
Distributions from affiliates [Abstract]
Contribution received from member														50,000,000
Distributions to member/parent														$ 110,000,000	135,000,000	115,000,000
Cleco Power [Member] | Maximum [Member]
Condensed Financial Statements, Captions [Line Items]
Ratio of total indebtedness to total capitalization (in hundredths)		0.65										0.65	0.65	0.65
Predecessor [Member]
Distributions from affiliates [Abstract]
Distributions to member/parent	$ 0						$ 0
Predecessor [Member] | Cleco Holdings [Member]
Distributions from affiliates [Abstract]
Cash distributions received from affiliates						$ 25,325,000									135,850,000	116,725,000
Equity contributions made to affiliates						0
Predecessor [Member] | Cleco Holdings [Member] | Cleco Power [Member]
Distributions from affiliates [Abstract]
Cash distributions received from affiliates						25,000,000									135,000,000	115,000,000
Equity contributions made to affiliates																138,100,000
Predecessor [Member] | Cleco Holdings [Member] | Perryville [Member]
Distributions from affiliates [Abstract]
Cash distributions received from affiliates						200,000									500,000	975,000
Predecessor [Member] | Cleco Holdings [Member] | Attala [Member]
Distributions from affiliates [Abstract]
Cash distributions received from affiliates						$ 125,000									$ 350,000	$ 750,000
Successor [Member]
Distributions from affiliates [Abstract]
Distributions to member/parent		$ 32,765,000	$ 28,000,000	$ 28,000,000								$ 88,765,000
Successor [Member] | Cleco Holdings [Member]
Distributions from affiliates [Abstract]
Cash distributions received from affiliates													$ 85,250,000
Equity contributions made to affiliates													50,000,000
Successor [Member] | Cleco Holdings [Member] | Cleco Power [Member]
Distributions from affiliates [Abstract]
Cash distributions received from affiliates													85,000,000
Successor [Member] | Cleco Holdings [Member] | Perryville [Member]
Distributions from affiliates [Abstract]
Cash distributions received from affiliates													150,000
Successor [Member] | Cleco Holdings [Member] | Attala [Member]
Distributions from affiliates [Abstract]
Cash distributions received from affiliates													100,000
Successor [Member] | Cleco Holdings [Member] | Cleco Group [Member]
Distributions from affiliates [Abstract]
Contribution received from member													100,700,000
Distributions to member/parent													$ 88,800,000

Schedule I Financial Stateme118

Schedule I Financial Statements of Cleco Corporation, Income Taxes (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Successor [Member]
Income Taxes [Abstract]
Federal and state income tax benefit		$ (22,822)
Successor [Member] | Cleco Holdings [Member]
Income Taxes [Abstract]
Federal and state income tax benefit		(22,937)
Equity income from subsidiaries - Federal and state income tax (benefit) expense		$ 115
Predecessor [Member]
Income Taxes [Abstract]
Federal and state income tax benefit	$ 3,468		$ 77,704	$ 67,116
Predecessor [Member] | Cleco Holdings [Member]
Income Taxes [Abstract]
Federal and state income tax benefit	(9,690)		(1,861)	(9,972)
Equity income from subsidiaries - Federal and state income tax (benefit) expense	$ 13,158		$ 79,565	$ 77,088

Schedule II Valuation and Qu119

Schedule II Valuation and Qualifying Accounts (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended	12 Months Ended
	Apr. 12, 2016	Dec. 31, 2016	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cleco Power [Member] | Allowance for Uncollectible Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	$ 2,674		$ 2,674	$ 922	$ 849
Additions charged to costs and expenses			5,511	2,986	1,980
Uncollectible account write-offs less recoveries			986	1,234	1,907
Balance at end of period		$ 7,199	7,199	2,674	922
Cleco Power [Member] | Unrestricted Storm Reserve [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	2,801		2,801	3,322	1,236
Additions			71	0	4,133
Deductions			265	521	2,047
Balance at end of period		2,607	2,607	2,801	3,322
Cleco Power [Member] | Restricted Storm Reserve [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	16,177		16,177	14,916	17,646
Additions			1,208	1,261	1,414
Deductions			0	0	4,144
Balance at end of period		17,385	17,385	16,177	14,916
Successor [Member] | Allowance for Uncollectible Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period		3,336
Additions charged to costs and expenses		4,348
Uncollectible account write-offs less recoveries		485
Balance at end of period	3,336	7,199	7,199
Successor [Member] | Unrestricted Storm Reserve [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period		2,536
Additions		71
Deductions		0
Balance at end of period	2,536	2,607	2,607
Successor [Member] | Restricted Storm Reserve [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period		16,515
Additions		870
Deductions		0
Balance at end of period	16,515	17,385	17,385
Predecessor [Member] | Allowance for Uncollectible Accounts [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	2,674	3,336	2,674	922	849
Additions charged to costs and expenses	1,163			2,986	1,980
Uncollectible account write-offs less recoveries	501			1,234	1,907
Balance at end of period	3,336			2,674	922
Predecessor [Member] | Unrestricted Storm Reserve [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	2,801	2,536	2,801	3,322	1,236
Additions	0			0	4,133
Deductions	265			521	2,047
Balance at end of period	2,536			2,801	3,322
Predecessor [Member] | Restricted Storm Reserve [Member]
Movement in Valuation Allowances and Reserves [Roll Forward]
Balance at beginning of period	16,177	$ 16,515	$ 16,177	14,916	17,646
Additions	338			1,261	1,414
Deductions	0			0	4,144
Balance at end of period	$ 16,515			$ 16,177	$ 14,916