Cleco Power 10-Q 28 Apr 14 2014 Q1 Quarterly report Financial data

Document_And_Entity_Informatio

Document And Entity Information	3 Months Ended
	Mar. 31, 2014	Apr. 22, 2014
Entity Information [Line Items]	'	'
Entity Registrant Name	'CLECO CORP	'
Entity Central Index Key	'0001089819	'
Current Fiscal Year End Date	'--12-31	'
Entity Filer Category	'Large Accelerated Filer	'
Document Type	'10-Q	'
Document Period End Date	31-Mar-14	'
Document Fiscal Year Focus	'2014	'
Document Fiscal Period Focus	'Q1	'
Amendment Flag	'false	'
Entity Common Stock, Shares Outstanding	'	60,359,534
Cleco Power [Member]	'	'
Entity Information [Line Items]	'	'
Entity Registrant Name	'CLECO POWER LLC	'
Entity Central Index Key	'0000018672	'
Entity Filer Category	'Non-accelerated Filer	'

Consolidated_Statements_of_Inc

Consolidated Statements of Income (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating revenue	'	'
Electric operations	$269,759	$229,425
Other operations	14,814	11,543
Affiliate revenue	0	0
Gross operating revenue	284,573	240,968
Electric customer credits	-186	-21
Operating revenue, net	284,387	240,947
Operating expenses	'	'
Fuel used for electric generation	59,047	85,365
Power purchased for utility customers	52,724	4,856
Other operations	26,993	26,924
Maintenance	32,369	17,635
Depreciation	41,741	34,032
Taxes other than income taxes	14,106	12,634
Loss (gain) on sale of assets	69	1,034
Total operating expenses	227,049	182,480
Operating income	57,338	58,467
Interest income	602	201
Allowance for other funds used during construction	1,631	1,164
Other income	971	2,273
Other expense	-672	-435
Interest charges	'	'
Interest charges, including amortization of debt expense, premium, and discount, net	20,758	21,831
Allowance for borrowed funds used during construction	-490	-375
Total interest charges	20,268	21,456
Income before income taxes	39,602	40,214
Federal and state income tax expense	13,678	13,081
Net income	25,924	27,133
Net income applicable to common stock	25,924	27,133
Average shares of common stock outstanding	'	'
Average number of basic common shares outstanding (in shares)	60,472,969	60,399,697
Average number of diluted common shares outstanding (in shares)	60,713,587	60,667,401
Basic earnings per share	'	'
Net income applicable to common stock (in dollars per share)	$0.43	$0.45
Diluted earnings per share	'	'
Net income applicable to common stock (in dollars per share)	$0.43	$0.45
Cash dividends paid per share of common stock	$0.36	$0.34
Cleco Power [Member]	'	'
Operating revenue	'	'
Electric operations	269,759	229,425
Other operations	14,272	11,038
Affiliate revenue	335	336
Gross operating revenue	284,366	240,799
Electric customer credits	-186	-21
Operating revenue, net	284,180	240,778
Operating expenses	'	'
Fuel used for electric generation	59,047	85,365
Power purchased for utility customers	58,191	9,693
Other operations	25,321	25,373
Maintenance	30,256	14,794
Depreciation	40,203	32,330
Taxes other than income taxes	12,974	11,458
Total operating expenses	225,992	179,013
Operating income	58,188	61,765
Interest income	602	198
Allowance for other funds used during construction	1,631	1,164
Other income	363	697
Other expense	-509	-444
Interest charges	'	'
Interest charges, including amortization of debt expense, premium, and discount, net	20,248	21,724
Allowance for borrowed funds used during construction	-490	-375
Total interest charges	19,758	21,349
Income before income taxes	40,517	42,031
Federal and state income tax expense	14,210	14,238
Net income	$26,307	$27,793

Consolidated_Statements_of_Com

Consolidated Statements of Comprehensive Income (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Net Income	$25,924	$27,133
Other comprehensive income, net of tax:	'	'
Amortization of postretirement benefits (net of tax)	844	536
Net gain on cash flow hedges (net of tax)	53	1,337
Total other comprehensive income, net of tax	897	1,873
Comprehensive income, net of tax	26,821	29,006
Cleco Power [Member]	'	'
Net Income	26,307	27,793
Other comprehensive income, net of tax:	'	'
Amortization of postretirement benefits (net of tax)	525	251
Net gain on cash flow hedges (net of tax)	53	1,337
Total other comprehensive income, net of tax	578	1,588
Comprehensive income, net of tax	$26,885	$29,381

Consolidated_Statements_of_Com1

Consolidated Statements of Comprehensive Income (Parenthetical) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Net tax expense of amortization of postretirement benefits	$528	$336
Net tax expense on cash flow hedges	33	836
Cleco Power [Member]	'	'
Net tax expense of amortization of postretirement benefits	328	157
Net tax expense on cash flow hedges	$33	$836

Consolidated_Balance_Sheets

Consolidated Balance Sheets (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Current assets	'	'
Cash and cash equivalents	$18,157	$28,656
Restricted cash and cash equivalents	3,893	8,986
Customer accounts receivable (less allowance for doubtful accounts)	48,936	50,567
Other accounts receivable	51,836	46,981
Unbilled revenue	25,452	31,166
Fuel inventory, at average cost	53,644	60,913
Material and supplies inventory, at average cost	63,095	62,811
Energy risk management asset	3,972	9,020
Accumulated deferred federal and state income taxes, net	72,180	94,179
Accumulated deferred fuel	1,582	0
Cash surrender value of company-/trust-owned life insurance policies	67,237	64,720
Prepayments	5,945	9,204
Regulatory assets- other	5,930	5,975
Other current assets	1,575	404
Total current assets	423,434	473,582
Property, plant, and equipment	'	'
Property, plant, and equipment	4,326,317	4,326,522
Accumulated depreciation	-1,371,281	-1,351,223
Net property, plant, and equipment	2,955,036	2,975,299
Construction work in progress	156,048	107,841
Total property, plant, and equipment, net	3,111,084	3,083,140
Equity investment in investees	14,540	14,540
Prepayments	4,532	4,510
Restricted cash and cash equivalents	14,494	5,033
Restricted investments	0	12,829
Regulatory assets - deferred taxes, net	230,489	229,173
Regulatory assets - other	245,185	249,677
Net investment in direct financing lease	13,517	13,523
Intangible asset	102,487	106,007
Other deferred charges	23,235	23,248
Total assets	4,182,997	4,215,262
Current liabilities	'	'
Long-term debt due within one year	17,688	17,182
Accounts payable	111,454	110,544
Customer deposits	50,247	48,456
Provision for rate refund	3,720	3,533
Taxes payable	18,766	18,680
Interest accrued	29,472	12,188
Accumulated deferred fuel	0	3,869
Energy risk management liabilities	64	382
Deferred compensation	10,852	11,081
Uncertain tax positions	4,610	4,610
Other current liabilities	14,198	12,948
Total current liabilities	261,071	243,473
Long-term liabilities and deferred credits	'	'
Accumulated deferred federal and state income taxes, net	860,033	869,150
Accumulated deferred investment tax credits	4,905	5,144
Postretirement benefit obligations	104,189	103,483
Restricted storm reserve	14,025	17,646
Tax credit fund investment, net	32,350	41,840
Contingent sale obligations	900	900
Other deferred credits	31,777	31,929
Total long-term liabilities and deferred credits	1,048,179	1,070,092
Capitalization	'	'
Long-term debt, net	1,296,965	1,315,500
Total liabilities	2,606,215	2,629,065
Commitments and Contingencies	'	'
Shareholders' equity	'	'
Common stock	61,051	61,047
Premium on common stock	415,708	422,624
Retained earnings	1,152,801	1,149,003
Treasury stock, at cost	-27,799	-20,601
Accumulated other comprehensive loss	-24,979	-25,876
Total shareholders' equity	1,576,782	1,586,197
Total liabilities and shareholders' equity	4,182,997	4,215,262
Cleco Power [Member]	'	'
Current assets	'	'
Cash and cash equivalents	11,464	21,055
Restricted cash and cash equivalents	3,893	8,986
Customer accounts receivable (less allowance for doubtful accounts)	48,936	50,567
Accounts receivable - affiliate	2,932	1,045
Other accounts receivable	51,804	46,939
Unbilled revenue	25,452	31,166
Fuel inventory, at average cost	53,644	60,913
Material and supplies inventory, at average cost	63,095	59,964
Energy risk management asset	3,972	9,020
Accumulated deferred federal and state income taxes, net	58,256	80,981
Accumulated deferred fuel	1,582	0
Cash surrender value of company-/trust-owned life insurance policies	19,420	19,326
Prepayments	4,166	7,074
Regulatory assets- other	5,930	5,975
Other current assets	1,177	388
Total current assets	355,723	403,399
Property, plant, and equipment	'	'
Property, plant, and equipment	4,311,221	4,052,774
Accumulated depreciation	-1,361,984	-1,260,843
Net property, plant, and equipment	2,949,237	2,791,931
Construction work in progress	152,386	104,113
Total property, plant, and equipment, net	3,101,623	2,896,044
Equity investment in investees	14,532	14,532
Prepayments	4,532	4,510
Restricted cash and cash equivalents	14,473	5,012
Restricted investments	0	12,829
Regulatory assets - deferred taxes, net	230,489	229,173
Regulatory assets - other	245,185	249,677
Intangible asset	102,487	106,007
Other deferred charges	22,540	22,529
Total assets	4,091,584	3,943,712
Current liabilities	'	'
Long-term debt due within one year	17,688	17,182
Accounts payable	105,784	98,785
Accounts payable - affiliate	7,793	8,386
Customer deposits	50,247	48,456
Provision for rate refund	3,720	3,533
Taxes payable	982	6,700
Interest accrued	27,977	13,589
Accumulated deferred fuel	0	3,869
Energy risk management liabilities	64	382
Other current liabilities	10,904	9,791
Total current liabilities	225,159	210,673
Long-term liabilities and deferred credits	'	'
Accumulated deferred federal and state income taxes, net	980,908	945,559
Accumulated deferred investment tax credits	4,905	5,144
Postretirement benefit obligations	53,249	52,953
Restricted storm reserve	14,025	17,646
Other deferred credits	30,835	30,664
Total long-term liabilities and deferred credits	1,083,922	1,051,966
Capitalization	'	'
Long-term debt, net	1,281,965	1,310,500
Total capitalization	2,782,503	2,681,073
Commitments and Contingencies	'	'
Shareholders' equity	'	'
Accumulated other comprehensive loss	-14,599	-15,177
Total shareholders' equity	1,500,538	1,370,573
Total liabilities and shareholders' equity	$4,091,584	$3,943,712

Consolidated_Balance_Sheets_Pa

Consolidated Balance Sheets (Parenthetical) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, except Share data, unless otherwise specified
Current assets	'	'
Customer accounts receivable, allowance for doubtful accounts	$723	$849
Shareholders' equity	'	'
Common stock, par value (in dollars per share)	$1	$1
Common stock, authorized (in shares)	100,000,000	100,000,000
Common stock, issued (in shares)	61,051,286	61,047,006
Common stock, outstanding (in shares)	60,359,534	60,454,520
Treasury stock, at cost (in shares)	691,752	592,486
Cleco Power [Member]	'	'
Current assets	'	'
Customer accounts receivable, allowance for doubtful accounts	$723	$849

Consolidated_Statements_of_Cas

Consolidated Statements of Cash Flows (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Operating activities	'	'
Net Income	$25,924	$27,133
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	45,137	38,586
Unearned compensation expense	1,977	1,510
Allowance for other funds used during construction	-1,631	-1,164
Net deferred income taxes	10,366	10,030
Deferred fuel costs	-148	4,493
Cash surrender value of company-/trust-owned life insurance	-1,113	-2,071
Changes in assets and liabilities:	'	'
Accounts receivable	-1,541	12,059
Unbilled revenue	5,714	4,845
Fuel, materials and supplies inventory	6,985	10,619
Prepayments	3,237	1,628
Accounts payable	-13,672	-37,345
Customer deposits	2,598	3,074
Postretirement benefit obligations	2,142	-32,422
Regulatory assets and liabilities, net	-4,367	-4,836
Other deferred accounts	-4,691	2,121
Taxes accrued	-3,702	55,930
Interest accrued	17,283	13,276
Other operating	46	-4,019
Net cash provided by operating activities	90,544	103,447
Investing activities	'	'
Additions to property, plant, and equipment	-47,139	-44,887
Allowance for other funds used during construction	1,631	1,164
Return of investment in company-owned life insurance	1,303	0
Premiums paid on company-/trust-owned life insurance	-1,404	0
Return of equity investment in tax credit fund	478	9
Contributions to tax credit fund	-11,182	-12,081
Transfer of cash (to) from restricted accounts	-4,367	5,154
Purchase of restricted investments	0	-1,447
Sale of restricted investments	11,138	0
Maturity of restricted investments	1,458	1,409
Other investing	122	969
Net cash used in investing activities	-47,962	-49,710
Financing activities	'	'
Draws on credit facility	40,000	108,000
Payments on credit facility	-50,000	-118,000
Issuance of long-term debt	0	60,000
Retirement of long-term debt	-7,581	-7,129
Repurchase of long-term debt	0	-60,000
Repurchase of common stock	-12,449	0
Dividends paid on common stock	-22,450	-20,593
Other financing	-601	-568
Net cash used in financing activities	-53,081	-38,290
Net increase (decrease) in cash and cash equivalents	-10,499	15,447
Cash and cash equivalents at beginning of period	28,656	31,020
Cash and cash equivalents at end of period	18,157	46,467
Supplementary cash flow information	'	'
Interest paid (net of amount capitalized)	4,346	6,326
Income taxes paid (refunded), net	9,971	-45,343
Supplementary non-cash investing and financing activities	'	'
Accrued additions to property, plant, and equipment	29,476	9,191
Non-cash additions to property, plant, and equipment, net	0	1,134
Employee Stock [Member] | Common Stock [Member]	'	'
Supplementary non-cash investing and financing activities	'	'
Issuance of common stock - ESPP	75	78
Cleco Power [Member]	'	'
Operating activities	'	'
Net Income	26,307	27,793
Adjustments to reconcile net income to net cash provided by operating activities:	'	'
Depreciation and amortization	42,358	35,094
Allowance for other funds used during construction	-1,631	-1,164
Net deferred income taxes	14,472	14,560
Deferred fuel costs	-148	4,493
Changes in assets and liabilities:	'	'
Accounts receivable	-1,524	12,098
Accounts and notes receivable, affiliate	-1,389	2,033
Unbilled revenue	5,714	4,845
Fuel, materials and supplies inventory	7,018	10,655
Prepayments	3,055	1,062
Accounts payable	-7,806	-31,744
Accounts and notes payable, affiliate	-1,150	-3,621
Customer deposits	2,598	3,074
Postretirement benefit obligations	1,307	-32,903
Regulatory assets and liabilities, net	-4,367	-4,836
Other deferred accounts	-4,691	1,650
Taxes accrued	-5,719	8,688
Interest accrued	14,388	13,457
Other operating	403	-2,136
Net cash provided by operating activities	89,195	63,098
Investing activities	'	'
Additions to property, plant, and equipment	-46,894	-43,599
Allowance for other funds used during construction	1,631	1,164
Return of investment in company-owned life insurance	1,303	0
Transfer of cash (to) from restricted accounts	-4,367	5,154
Purchase of restricted investments	0	-1,447
Sale of restricted investments	11,138	0
Maturity of restricted investments	1,458	1,409
Other investing	123	988
Net cash used in investing activities	-35,608	-36,331
Financing activities	'	'
Draws on credit facility	20,000	90,000
Payments on credit facility	-40,000	-90,000
Issuance of long-term debt	0	60,000
Retirement of long-term debt	-7,581	-7,129
Repurchase of long-term debt	0	-60,000
Distribution to parent	-35,000	0
Other financing	-597	-567
Net cash used in financing activities	-63,178	-7,696
Net increase (decrease) in cash and cash equivalents	-9,591	19,071
Cash and cash equivalents at beginning of period	21,055	23,368
Cash and cash equivalents at end of period	11,464	42,439
Supplementary cash flow information	'	'
Interest paid (net of amount capitalized)	4,381	6,260
Income taxes paid (refunded), net	-788	0
Supplementary non-cash investing and financing activities	'	'
Accrued additions to property, plant, and equipment	29,381	7,634
Non-cash additions to property, plant, and equipment, net	$176,244	$1,134

Consolidated_Statement_of_Chan

Consolidated Statement of Changes in Common Shareholders' Equity (USD $)	Total	Common Stock [Member]	Treasury Stock [Member]	Premium on Common Stock [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
In Thousands, except Share data, unless otherwise specified
Stockholders' equity, Beginning Balance at Dec. 31, 2012	$1,499,213	$60,962	($21,072)	$416,619	$1,075,074	($32,370)
Treasury stock, Beginning Balance (in shares) at Dec. 31, 2012	'	'	-606,025	'	'	'
Common stock issued, Beginning Balance (in shares) at Dec. 31, 2012	'	60,961,570	'	'	'	'
Stock Issued or Granted During Period, Share-based Compensation [Abstract]	'	'	'	'	'	'
Common stock issued for compensatory plans, Value	1,455	85	110	1,260	'	'
Common stock issued for compensatory plans (in shares)	'	85,436	3,159	'	'	'
Treasury Stock Acquired [Abstract]	'	'	'	'	'	'
Repurchase of common stock (in shares)	0	'	'	'	'	'
Dividends on common stock	-20,544	'	'	'	-20,544	'
Net Income	27,133	'	'	'	27,133	'
Other comprehensive income, net of tax	1,873	'	'	'	'	1,873
Stockholders' equity, Ending Balance at Mar. 31, 2013	1,509,130	61,047	-20,962	417,879	1,081,663	-30,497
Treasury stock, Ending Balance (in shares) at Mar. 31, 2013	'	'	-602,866	'	'	'
Common stock issued, Ending Balance (in shares) at Mar. 31, 2013	'	61,047,006	'	'	'	'
Stockholders' equity, Beginning Balance at Dec. 31, 2013	1,586,197	61,047	-20,601	422,624	1,149,003	-25,876
Treasury stock, Beginning Balance (in shares) at Dec. 31, 2013	-592,486	'	-592,486	'	'	'
Common stock issued, Beginning Balance (in shares) at Dec. 31, 2013	61,047,006	61,047,006	'	'	'	'
Stock Issued or Granted During Period, Share-based Compensation [Abstract]	'	'	'	'	'	'
Common stock issued for compensatory plans, Value	-1,661	4	5,251	-6,916	'	'
Common stock issued for compensatory plans (in shares)	'	4,280	150,734	'	'	'
Treasury Stock Acquired [Abstract]	'	'	'	'	'	'
Repurchase of common stock, Value	-12,449	'	-12,449	'	'	'
Repurchase of common stock (in shares)	-250,000	'	-250,000	'	'	'
Dividends on common stock	-22,126	'	'	'	-22,126	'
Net Income	25,924	'	'	'	25,924	'
Other comprehensive income, net of tax	897	'	'	'	'	897
Stockholders' equity, Ending Balance at Mar. 31, 2014	$1,576,782	$61,051	($27,799)	$415,708	$1,152,801	($24,979)
Treasury stock, Ending Balance (in shares) at Mar. 31, 2014	-691,752	'	-691,752	'	'	'
Common stock issued, Ending Balance (in shares) at Mar. 31, 2014	61,051,286	61,051,286	'	'	'	'

Consolidated_Statement_of_Chan1

Consolidated Statement of Changes in Common Shareholders' Equity (Parenthetical) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Statement of Stockholders' Equity [Abstract]	'	'
Dividends on common stock (in dollars per share)	$0.36	$0.34

Consolidated_Statement_of_Chan2

Consolidated Statement of Changes in Member's Equity (USD $)	Total	Accumulated Other Comprehensive Income (Loss) [Member]	Cleco Power [Member]	Cleco Power [Member]	Cleco Power [Member]
In Thousands, unless otherwise specified				Member's Equity [Member]	Accumulated Other Comprehensive Income (Loss) [Member]
Stockholders' equity, Beginning Balance at Dec. 31, 2012	$1,499,213	($32,370)	$1,319,919	$1,340,340	($20,421)
Increase (Decrease) in Member's Equity [Roll Forward]	'	'	'	'	'
Other comprehensive income, net of tax	1,873	1,873	1,588	'	1,588
Net Income	27,133	'	27,793	27,793	'
Stockholders' equity, Ending Balance at Mar. 31, 2013	1,509,130	-30,497	1,349,300	1,368,133	-18,833
Stockholders' equity, Beginning Balance at Dec. 31, 2013	1,586,197	-25,876	1,370,573	1,385,750	-15,177
Increase (Decrease) in Member's Equity [Roll Forward]	'	'	'	'	'
Other comprehensive income, net of tax	897	897	578	'	578
Contributions	'	'	138,080	138,080	'
Distributions to parent	'	'	-35,000	-35,000	'
Net Income	25,924	'	26,307	26,307	'
Stockholders' equity, Ending Balance at Mar. 31, 2014	$1,576,782	($24,979)	$1,500,538	$1,515,137	($14,599)

Summary_of_Significant_Account

Summary of Significant Accounting Policies	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Summary of Significant Accounting Policies	'
	Note 1 — Summary of Significant Accounting Policies
	Principles of Consolidation
	The accompanying Condensed Consolidated Financial Statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.
	Basis of Presentation
	The Condensed Consolidated Financial Statements of Cleco Corporation and Cleco Power have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all of the information and notes required by GAAP for annual financial statements. The year-end Condensed Consolidated Balance Sheet data was derived from audited financial statements. Because the interim Condensed Consolidated Financial Statements and the accompanying notes do not include all of the information and notes required by GAAP for annual financial statements, the Condensed Consolidated Financial Statements and other information included in this quarterly report should be read in conjunction with the consolidated financial statements and accompanying notes in the Registrants’ Combined Annual Report on Form 10-K for the year ended December 31, 2013.
	These Condensed Consolidated Financial Statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly present the financial position and results of operations of Cleco. Amounts reported in Cleco’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, and other factors.
	In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates. For more information on recent authoritative guidance and its effect on financial results, see Note 2 — “Recent Authoritative Guidance.”
	Property, Plant, and Equipment
	Property, plant, and equipment consists primarily of regulated utility generation and energy transmission 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.
	During the first quarter of 2014, Cleco’s investment in regulated utility property, plant, and equipment increased primarily due to the transfer of Coughlin from Midstream to Cleco Power. The transfer of Coughlin was recorded on Cleco Power’s books at the historical carrying value of approximately $176.0 million, net of the related accumulated depreciation of $82.6 million. The transfer of Coughlin was accounted for as a business under common control, which is typically accounted for as if the transfer had occurred at the beginning of the period. However, 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 Power’s financial statements were not retrospectively adjusted to reflect the transfer. For more information regarding the Coughlin transfer, see Note 14 — “Coughlin Transfer.”
	Cleco’s property, plant, and equipment consisted of:
	(THOUSANDS)	AT MAR. 31, 2014			AT DEC. 31, 2013
	Regulated utility plants	$	4,311,221		$	4,052,774
	Other	15,096			273,748
	Total property, plant, and equipment	4,326,317			4,326,522
	Accumulated depreciation	(1,371,281		)	(1,351,223		)
	Net property, plant, and equipment	$	2,955,036		$	2,975,299
	Restricted Cash and Cash Equivalents
	Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general corporate purposes. Cleco’s restricted cash and cash equivalents consisted of:
	(THOUSANDS)	AT MAR. 31, 2014			AT DEC. 31, 2013
	Diversified Lands’ mitigation escrow	$	21		$	21
	Cleco Katrina/Rita’s storm recovery bonds	3,893			8,986
	Cleco Power’s future storm restoration costs	14,025			4,726
	Cleco Power’s building renovation escrow	448			286
	Total restricted cash and cash equivalents	$	18,387		$	14,019
	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. During the three months ended March 31, 2014, Cleco Katrina/Rita collected $5.5 million net of administration fees. In March 2014, Cleco Katrina/Rita used $7.6 million for scheduled storm recovery bond principal payments and $3.0 million for related interest.
	Cleco Power’s restricted cash and cash equivalents held for future storm restoration costs increased $9.3 million from December 31, 2013, primarily due to the transfer of $13.2 million of restricted investments that were held with an outside investment manager and liquidated during the first quarter of 2014. The liquidated holdings are now held in restricted cash and cash equivalents and reported in the above table in Cleco Power’s future storm restoration costs. Partially offsetting this amount was the transfer of $4.0 million to cover the expenses associated with recent storm activity.
	In connection with Cleco Power’s building modernization project, Cleco Power was required to establish an escrow account with a qualified financial institution and deposit all retainage monies as they accrue under the construction contract. Upon completion of the construction work, the funds including any interest held in the escrow account will be released from escrow and paid to the construction contractor.
	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 are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP. For more information about fair value levels, see Note 4 — “Fair Value Accounting.”
	Risk Management
	Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes 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 applies the authoritative guidance as it relates to derivatives and hedging to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market. Generally, Cleco Power’s market risk-sensitive instruments and positions qualify for the normal-purchase, normal-sale exception to mark-to-market accounting because Cleco Power takes physical delivery and the instruments and positions are used to satisfy customer requirements.
	Cleco Power may also enter into 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 are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of energy risk management assets or liabilities. Such gain or loss is deferred as a component of deferred fuel assets or liabilities in accordance with regulatory policy. When these positions close, actual gains or losses will be included in the FAC and reflected on customers’ bills as a component of the fuel cost adjustment. As part of the integration into MISO, Cleco Power was awarded FTRs in November 2013. Cleco Power also purchased FTRs in auctions facilitated by MISO. FTRs provide a financial hedge to manage the risk of congestion cost in the Day-Ahead Energy Market. FTRs represent rights to congestion credits or charges along a transmission path during a given time frame for a certain MW quantity. At March 31, 2014, Cleco and Cleco Power's Condensed Consolidated Balance Sheets reflected open FTR positions of $4.0 million in Energy risk management assets and $0.1 million in Energy risk management liabilities, compared with $9.0 million in Energy risk management assets and $0.4 million in Energy risk management liabilities at December 31, 2013. There were no open natural gas positions at March 31, 2014 or December 31, 2013.
	Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, counterparty credit exposure, and counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and by 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 has entered into various 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 more information on the interest rate risk contracts, see Note 4 — “Fair Value Accounting — Derivatives and Hedging.”
	Accounting for MISO Transactions
	Cleco Power participates in the energy market through MISO. MISO requires Cleco Power to submit hourly day-ahead, real time and FTR bids and offers for energy at locations across the MISO region. In each monthly reporting period, the hourly sale and purchase net amounts are aggregated and separately reported in Electric operations or Power purchased for utility customers on Cleco’s Condensed Consolidated Statements of Income. For more information on FTRs, see Note 4 — “Fair Value Accounting — Derivatives and Hedging.”
	Earnings per Average Common Share
	The following tables show the calculation of basic and diluted earnings per share:
											FOR THE THREE MONTHS ENDED MAR. 31,
								2014							2013
	(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME			SHARES			PER SHARE			INCOME			SHARES	PER SHARE
								AMOUNT							AMOUNT
	Basic net income applicable to common stock	$	25,924		60,472,969			$	0.43		$	27,133		60,399,697	$	0.45
	Effect of dilutive securities
	Add:  restricted stock (LTICP)				240,618									267,704
	Diluted net income applicable to common stock	$	25,924		60,713,587			$	0.43		$	27,133		60,667,401	$	0.45
	Stock option grants are excluded from the computation of diluted earnings per share if the exercise price is higher than the average market price. All stock options were exercised during 2012 and no additional options were granted through March 31, 2014. Therefore, no stock option grants were excluded from the computation of diluted earnings per share for the three months ended March 31, 2014 and 2013.
	Stock-Based Compensation
	At March 31, 2014, Cleco had two stock-based compensation plans, the ESPP and the LTICP. Substantially all employees, excluding officers and general managers, may choose to participate in the ESPP and purchase a limited amount of common stock at a discount through a stock option agreement. Options or restricted shares of stock, known as non-vested stock as defined by the authoritative guidance on stock-based compensation, common stock equivalents, and stock appreciation rights may be granted to certain officers, key employees, or directors of Cleco Corporation and its subsidiaries pursuant to the LTICP.
	During the three months ended March 31, 2014, Cleco granted 120,935 shares of non-vested stock to certain officers, and key employees of Cleco Corporation and its subsidiaries pursuant to the LTICP.
	Cleco and Cleco Power reported pre-tax compensation expense for their share-based compensation plans as shown in the following table:
		CLECO CORPORATION							CLECO POWER
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013				2014			2013
	Equity classification
	Non-vested stock	$	1,922		$	1,428			$	426		$	331
	Total equity classification	$	1,922		$	1,428			$	426		$	331
	Liability classification
	Common stock	$	—		$	1			$	—		$	—
	equivalent units
	Total pre-tax	$	1,922		$	1,429			$	426		$	331
	compensation expense
Tax benefit	$	739		$	550			$	164		$	127
Common Stock Repurchase Program
In January 2011, Cleco Corporation’s Board of Directors approved the implementation of a new common stock repurchase program. This program authorizes management to repurchase, from time to time, shares of common stock so that Cleco’s diluted average shares of common stock outstanding remain approximately equal to its diluted average shares of common stock outstanding for 2010. Under this program, purchases may be made on a discretionary basis at times and in amounts as determined by management, subject to market conditions, legal requirements and other factors. Purchases under the program will not be announced in advance and may be made in the open market or through privately negotiated transactions. During the three months ended March 31, 2014, 250,000 shares of common stock were repurchased by Cleco Corporation. During the three months ended March 31, 2013, Cleco Corporation repurchased no shares of common stock.

Recent_Authoritative_Guidance

Recent Authoritative Guidance	3 Months Ended
	Mar. 31, 2014
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]	'
New Accounting Pronouncements and Changes in Accounting Principles [Text Block]	'
	Note 2 — Recent Authoritative Guidance
	The Registrants adopted, or will adopt, the recent authoritative guidance listed below on their respective effective dates.
	In February 2013, FASB revised the disclosure requirements related to items reclassified out of accumulated other comprehensive income. This guidance is intended to improve the transparency of changes in OCI. This revision is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. Cleco adopted the revisions to this amendment during the first quarter of 2013. The adoption of this revision did not have an impact on the financial condition, results of operations, or cash flows of the Registrants because it relates to disclosures. For more information on items reclassified out of accumulated other comprehensive income, see Note 13 — “Accumulated Other Comprehensive Loss.”
	In February 2013, FASB issued guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. The adoption of this guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance did not have an impact on the financial condition, results of operations, or cash flows of the Registrants.
	In April 2013, FASB issued guidance on applying the liquidation basis of accounting and the related disclosure requirements. Under this accounting standards update, an entity must use the liquidation basis of accounting to present its financial statements when it determines that liquidation is imminent, unless the liquidation is the same as that under the plan specified in an entity's governing documents created at its inception. The adoption of this standard is effective for entities that determine liquidation is imminent during annual reporting periods beginning after December 15, 2013, and interim reporting periods therein. The adoption of this guidance did not have an impact on the financial condition, results of operations, or cash flows of the Registrants.
	In July 2013, FASB amended the income tax guidance to provide for the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. The adoption of this guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance did not have an impact on the financial condition, results of operations, or cash flows of the Registrants.
	In January 2014, FASB amended the accounting guidance for investments in qualified affordable housing projects. This guidance modifies the conditions that must be met to present the pretax effects and related tax benefits of such investments as a component of income taxes. The adoption of this guidance is effective for annual periods and interim reporting periods within those annual periods, beginning after December 31, 2014. Management is currently evaluating the effect the adoption of this guidance will have on the financial condition, results of operations, or cash flows of the Registrants.
	In January 2014, FASB amended the accounting guidance for service concession arrangements. This guidance states that certain service concession arrangements with public-sector grantors are not within the scope of lease accounting. Operating entities entering into these arrangements should not recognize the related infrastructure as its property, plant and equipment and should apply other accounting guidance. The adoption of this guidance is effective for interim periods beginning after December 15, 2014. Management is currently evaluating the effect the adoption of this guidance will have on the financial condition, results of operations, or cash flows of the Registrants.
	In April 2014, FASB amended the accounting guidance for the reporting of discontinued operations. These amendments improve the definition of discontinued operations by limiting discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have or will have a major effect on an entity’s operations and financial results. This guidance also requires additional disclosures about discontinued operations. The adoption of this guidance is effective for all disposals (or classifications as held for sale) of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. The adoption of this guidance is not expected to have an effect on the financial condition, results of operations, or cash flows of the Registrants.
Recent Authoritative Guidance	'
	Note 1 — Summary of Significant Accounting Policies
	Principles of Consolidation
	The accompanying Condensed Consolidated Financial Statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.
	Basis of Presentation
	The Condensed Consolidated Financial Statements of Cleco Corporation and Cleco Power have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all of the information and notes required by GAAP for annual financial statements. The year-end Condensed Consolidated Balance Sheet data was derived from audited financial statements. Because the interim Condensed Consolidated Financial Statements and the accompanying notes do not include all of the information and notes required by GAAP for annual financial statements, the Condensed Consolidated Financial Statements and other information included in this quarterly report should be read in conjunction with the consolidated financial statements and accompanying notes in the Registrants’ Combined Annual Report on Form 10-K for the year ended December 31, 2013.
	These Condensed Consolidated Financial Statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly present the financial position and results of operations of Cleco. Amounts reported in Cleco’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, and other factors.
	In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates. For more information on recent authoritative guidance and its effect on financial results, see Note 2 — “Recent Authoritative Guidance.”
	Property, Plant, and Equipment
	Property, plant, and equipment consists primarily of regulated utility generation and energy transmission 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.
	During the first quarter of 2014, Cleco’s investment in regulated utility property, plant, and equipment increased primarily due to the transfer of Coughlin from Midstream to Cleco Power. The transfer of Coughlin was recorded on Cleco Power’s books at the historical carrying value of approximately $176.0 million, net of the related accumulated depreciation of $82.6 million. The transfer of Coughlin was accounted for as a business under common control, which is typically accounted for as if the transfer had occurred at the beginning of the period. However, 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 Power’s financial statements were not retrospectively adjusted to reflect the transfer. For more information regarding the Coughlin transfer, see Note 14 — “Coughlin Transfer.”
	Cleco’s property, plant, and equipment consisted of:
	(THOUSANDS)	AT MAR. 31, 2014			AT DEC. 31, 2013
	Regulated utility plants	$	4,311,221		$	4,052,774
	Other	15,096			273,748
	Total property, plant, and equipment	4,326,317			4,326,522
	Accumulated depreciation	(1,371,281		)	(1,351,223		)
	Net property, plant, and equipment	$	2,955,036		$	2,975,299
	Restricted Cash and Cash Equivalents
	Various agreements to which Cleco is subject contain covenants that restrict its use of cash. As certain provisions under these agreements are met, cash is transferred out of related escrow accounts and becomes available for its intended purposes and/or general corporate purposes. Cleco’s restricted cash and cash equivalents consisted of:
	(THOUSANDS)	AT MAR. 31, 2014			AT DEC. 31, 2013
	Diversified Lands’ mitigation escrow	$	21		$	21
	Cleco Katrina/Rita’s storm recovery bonds	3,893			8,986
	Cleco Power’s future storm restoration costs	14,025			4,726
	Cleco Power’s building renovation escrow	448			286
	Total restricted cash and cash equivalents	$	18,387		$	14,019
	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. During the three months ended March 31, 2014, Cleco Katrina/Rita collected $5.5 million net of administration fees. In March 2014, Cleco Katrina/Rita used $7.6 million for scheduled storm recovery bond principal payments and $3.0 million for related interest.
	Cleco Power’s restricted cash and cash equivalents held for future storm restoration costs increased $9.3 million from December 31, 2013, primarily due to the transfer of $13.2 million of restricted investments that were held with an outside investment manager and liquidated during the first quarter of 2014. The liquidated holdings are now held in restricted cash and cash equivalents and reported in the above table in Cleco Power’s future storm restoration costs. Partially offsetting this amount was the transfer of $4.0 million to cover the expenses associated with recent storm activity.
	In connection with Cleco Power’s building modernization project, Cleco Power was required to establish an escrow account with a qualified financial institution and deposit all retainage monies as they accrue under the construction contract. Upon completion of the construction work, the funds including any interest held in the escrow account will be released from escrow and paid to the construction contractor.
	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 are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP. For more information about fair value levels, see Note 4 — “Fair Value Accounting.”
	Risk Management
	Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes 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 applies the authoritative guidance as it relates to derivatives and hedging to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market. Generally, Cleco Power’s market risk-sensitive instruments and positions qualify for the normal-purchase, normal-sale exception to mark-to-market accounting because Cleco Power takes physical delivery and the instruments and positions are used to satisfy customer requirements.
	Cleco Power may also enter into 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 are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of energy risk management assets or liabilities. Such gain or loss is deferred as a component of deferred fuel assets or liabilities in accordance with regulatory policy. When these positions close, actual gains or losses will be included in the FAC and reflected on customers’ bills as a component of the fuel cost adjustment. As part of the integration into MISO, Cleco Power was awarded FTRs in November 2013. Cleco Power also purchased FTRs in auctions facilitated by MISO. FTRs provide a financial hedge to manage the risk of congestion cost in the Day-Ahead Energy Market. FTRs represent rights to congestion credits or charges along a transmission path during a given time frame for a certain MW quantity. At March 31, 2014, Cleco and Cleco Power's Condensed Consolidated Balance Sheets reflected open FTR positions of $4.0 million in Energy risk management assets and $0.1 million in Energy risk management liabilities, compared with $9.0 million in Energy risk management assets and $0.4 million in Energy risk management liabilities at December 31, 2013. There were no open natural gas positions at March 31, 2014 or December 31, 2013.
	Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, counterparty credit exposure, and counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and by 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 has entered into various 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 more information on the interest rate risk contracts, see Note 4 — “Fair Value Accounting — Derivatives and Hedging.”
	Accounting for MISO Transactions
	Cleco Power participates in the energy market through MISO. MISO requires Cleco Power to submit hourly day-ahead, real time and FTR bids and offers for energy at locations across the MISO region. In each monthly reporting period, the hourly sale and purchase net amounts are aggregated and separately reported in Electric operations or Power purchased for utility customers on Cleco’s Condensed Consolidated Statements of Income. For more information on FTRs, see Note 4 — “Fair Value Accounting — Derivatives and Hedging.”
	Earnings per Average Common Share
	The following tables show the calculation of basic and diluted earnings per share:
											FOR THE THREE MONTHS ENDED MAR. 31,
								2014							2013
	(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME			SHARES			PER SHARE			INCOME			SHARES	PER SHARE
								AMOUNT							AMOUNT
	Basic net income applicable to common stock	$	25,924		60,472,969			$	0.43		$	27,133		60,399,697	$	0.45
	Effect of dilutive securities
	Add:  restricted stock (LTICP)				240,618									267,704
	Diluted net income applicable to common stock	$	25,924		60,713,587			$	0.43		$	27,133		60,667,401	$	0.45
	Stock option grants are excluded from the computation of diluted earnings per share if the exercise price is higher than the average market price. All stock options were exercised during 2012 and no additional options were granted through March 31, 2014. Therefore, no stock option grants were excluded from the computation of diluted earnings per share for the three months ended March 31, 2014 and 2013.
	Stock-Based Compensation
	At March 31, 2014, Cleco had two stock-based compensation plans, the ESPP and the LTICP. Substantially all employees, excluding officers and general managers, may choose to participate in the ESPP and purchase a limited amount of common stock at a discount through a stock option agreement. Options or restricted shares of stock, known as non-vested stock as defined by the authoritative guidance on stock-based compensation, common stock equivalents, and stock appreciation rights may be granted to certain officers, key employees, or directors of Cleco Corporation and its subsidiaries pursuant to the LTICP.
	During the three months ended March 31, 2014, Cleco granted 120,935 shares of non-vested stock to certain officers, and key employees of Cleco Corporation and its subsidiaries pursuant to the LTICP.
	Cleco and Cleco Power reported pre-tax compensation expense for their share-based compensation plans as shown in the following table:
		CLECO CORPORATION							CLECO POWER
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013				2014			2013
	Equity classification
	Non-vested stock	$	1,922		$	1,428			$	426		$	331
	Total equity classification	$	1,922		$	1,428			$	426		$	331
	Liability classification
	Common stock	$	—		$	1			$	—		$	—
	equivalent units
	Total pre-tax	$	1,922		$	1,429			$	426		$	331
	compensation expense
Tax benefit	$	739		$	550			$	164		$	127
Common Stock Repurchase Program
In January 2011, Cleco Corporation’s Board of Directors approved the implementation of a new common stock repurchase program. This program authorizes management to repurchase, from time to time, shares of common stock so that Cleco’s diluted average shares of common stock outstanding remain approximately equal to its diluted average shares of common stock outstanding for 2010. Under this program, purchases may be made on a discretionary basis at times and in amounts as determined by management, subject to market conditions, legal requirements and other factors. Purchases under the program will not be announced in advance and may be made in the open market or through privately negotiated transactions. During the three months ended March 31, 2014, 250,000 shares of common stock were repurchased by Cleco Corporation. During the three months ended March 31, 2013, Cleco Corporation repurchased no shares of common stock.

Regulatory_Assets_and_Liabilit

Regulatory Assets and Liabilities	3 Months Ended
	Mar. 31, 2014
Regulatory Assets and Liabilities Disclosure [Abstract]	'
Regulatory Assets and Liabilities	'
	Note 3 — Regulatory Assets and Liabilities
	Cleco Power follows the authoritative guidance on regulated operations, which allows utilities to capitalize or defer certain costs based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process. The following table summarizes Cleco Power’s regulatory assets and liabilities at March 31, 2014 and December 31, 2013:
	(THOUSANDS)	AT MAR. 31, 2014		AT DEC. 31, 2013
	Regulatory assets – deferred taxes, net	$	230,489	$	229,173
	Mining costs	$	13,382	$	14,019
	Interest costs	5,853		5,943
	Asset removal costs	954		936
	Postretirement plan costs	91,638		93,333
	Tree trimming costs	5,560		4,840
	Training costs	7,136		7,175
	Surcredits, net	17,033		16,738
	Amended Lignite mining agreement contingency	3,781		3,781
	Power purchase agreement capacity costs	6,143		9,749
	AMI deferred revenue requirement	5,400		4,682
	Production Operations & Maintenance expenses	8,459		8,459
	AFUDC equity gross-up	73,257		73,306
	Rate case costs	—		45
	Acadia Unit 1 acquisition costs	2,734		2,760
	Financing costs	9,679		9,772
	Biomass costs	106		114
	Total regulatory assets – other	$	251,115	$	255,652
	Fuel and purchased power	1,582		(3,869		)
	Total regulatory assets, net	$	483,186	$	480,956
	Power Purchase Agreement Capacity Costs
	In March 2012, Cleco Power received approval from the LPSC for a three-year power purchase agreement with Evangeline providing 730 MW of capacity and energy beginning May 1, 2012 and ending April 30, 2015. The LPSC order allowed Cleco Power to defer and recover a portion of capacity costs associated with the power purchase agreement. On March 15, 2014, Coughlin was transferred to Cleco Power and the power purchase agreement was terminated. The recovery of the remaining capacity costs will be determined as part of Cleco Power’s FRP extension.
	Fuel and Purchased Power Costs
	The cost of fuel used for electric generation and the cost of power purchased for utility customers are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such charges. For the three months ended March 31, 2014, approximately 88% of Cleco Power’s total fuel cost was regulated by the LPSC, while the remainder was regulated by FERC.
	The $5.5 million change in the under/over recovered costs was primarily due to a $4.7 million decrease in net mark-to-market gains as a result of lower valuations of open FTR positions and the settlement of certain positions, and an $0.8 million increase in fuel and purchased power costs.

Fair_Value_Accounting

Fair Value Accounting	3 Months Ended
	Mar. 31, 2014
Fair Value Disclosures [Abstract]	'
Fair Value Accounting	'
	Note 4 — Fair Value Accounting
	The amounts reflected in Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2014 and December 31, 2013, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, accounts payable, and short-term debt 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 Condensed Consolidated Balance Sheets.
	Cleco
		AT MAR. 31, 2014								AT DEC. 31, 2013
	(THOUSANDS)	CARRYING				ESTIMATED				CARRYING			ESTIMATED
		VALUE				FAIR VALUE				VALUE			FAIR VALUE
	Financial instruments not marked-to-market:
	Cash equivalents	$	12,176			$	12,176			$	22,204		$	22,204
	Restricted cash equivalents	$	18,362			$	18,362			$	14,019		$	14,019
	Long-term debt, excluding debt issuance costs	$	1,313,649			$	1,473,263			$	1,331,230		$	1,420,048
	Cleco Power
		AT MAR. 31, 2014								AT DEC. 31, 2013
	(THOUSANDS)	CARRYING				ESTIMATED				CARRYING			ESTIMATED
		VALUE				FAIR VALUE				VALUE			FAIR VALUE
	Financial instruments not marked-to-market:
	Cash equivalents	$	5,900			$	5,900			$	14,900		$	14,900
	Restricted cash equivalents	$	18,341			$	18,341			$	13,998		$	13,998
	Long-term debt, excluding debt issuance costs	$	1,298,649			$	1,458,263			$	1,326,230		$	1,415,048
	Fair Value Measurements and Disclosures
	The authoritative guidance on fair value measurements requires entities to classify 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 and within the scope of the authoritative guidance for fair value measurements and disclosures.
	Cleco
		CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
	(THOUSANDS)	AT MAR. 31, 2014				QUOTED PRICES IN				SIGNIFICANT			SIGNIFICANT			AT DEC. 31, 2013		QUOTED PRICES IN		SIGNIFICANT		SIGNIFICANT
						ACTIVE MARKETS				OTHER			UNOBSERVABLE					ACTIVE MARKETS		OTHER		UNOBSERVABLE
						FOR IDENTICAL				OBSERVABLE			INPUTS					FOR IDENTICAL		OBSERVABLE		INPUTS
						ASSETS				INPUTS			(LEVEL 3)					ASSETS		INPUTS		(LEVEL 3)
						(LEVEL 1)				(LEVEL 2)								(LEVEL 1)		(LEVEL 2)
	Asset Description
	Institutional money market funds	$	30,538			$	—			$	30,538		$	—		$	36,100	$	—	$	36,100	$	—
	Commercial paper	—				—				—			—			1,483		—		1,483		—
	Municipal bonds	—				—				—			—			9,831		—		9,831		—
	Corporate bonds	—				—				—			—			515		—		515		—
	Federal agency mortgage-backed securities	—				—				—			—			1,000		—		1,000		—
	FTRs	3,972				—				—			3,972			9,020		—		—		9,020
	Total assets	$	34,510			$	—			$	30,538		$	3,972		$	57,949	$	—	$	48,929	$	9,020
	Liability Description
	Long-term debt	1,473,263				—				1,473,263			—			1,420,048		—		1,420,048		—
	FTRs	64				—				—			64			382		—		—		382
	Total liabilities	$	1,473,327			$	—			$	1,473,263		$	64		$	1,420,430	$	—	$	1,420,048	$	382
	Cleco Power
		CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
	(THOUSANDS)	AT MAR. 31, 2014				QUOTED PRICES IN				SIGNIFICANT			SIGNIFICANT			AT DEC. 31, 2013		QUOTED PRICES IN		SIGNIFICANT		SIGNIFICANT
						ACTIVE MARKETS				OTHER			UNOBSERVABLE					ACTIVE MARKETS		OTHER		UNOBSERVABLE
						FOR IDENTICAL				OBSERVABLE			INPUTS					FOR IDENTICAL		OBSERVABLE		INPUTS
						ASSETS				INPUTS			(LEVEL 3)					ASSETS		INPUTS		(LEVEL 3)
						(LEVEL 1)				(LEVEL 2)								(LEVEL 1)		(LEVEL 2)
	Asset Description
	Institutional money market funds	$	24,241			$	—			$	24,241		$	—		$	28,775	$	—	$	28,775	$	—
	Commercial paper	—				—				—			—			1,483		—		1,483		—
	Municipal bonds	—				—				—			—			9,831		—		9,831		—
	Corporate bonds	—				—				—			—			515		—		515		—
	Federal agency mortgage-backed securities	—				$	—			—			—			1,000		—		1,000		—
	FTRs	3,972				$	—			—			3,972			9,020		—		—		9,020
	Total assets	$	28,213			$	—			$	24,241		$	3,972		$	50,624	$	—	$	41,604	$	9,020
	Liability Description
	Long-term debt	1,458,263				—				1,458,263			—			1,415,048		—		1,415,048		—
	FTRs	64				—				—			64			382		—		—		382
	Total liabilities	$	1,458,327			$	—			$	1,458,263		$	64		$	1,415,430	$	—	$	1,415,048	$	382
	The following table summarizes the changes in the fair value of FTR assets and liabilities classified as Level 3 in the fair value hierarchy as of March 31, 2014:
	(THOUSANDS)
	Beginning balance at January 1, 2014	$	8,638
Realized losses	(747		)	*
Unrealized losses	(1,060		)	*
Purchases	(85		)
Sales	(321		)
Settlements	(2,517		)
Ending balance at March 31, 2014	$	3,908
* Unrealized gains and losses are reported in Accumulated deferred fuel on the balance sheet. As gains and losses are realized in future periods, they will be recorded as Electric operations or Power purchased for utility customers on the income statement.
The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions at March 31, 2014 and December 31, 2013:
	FAIR VALUE								VALUATION TECHNIQUE		SIGNIFICANT	FORWARD PRICE RANGE
											UNOBSERVABLE INPUTS
(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	Assets				Liabilities							Low			High
FTRs at Mar. 31, 2014	$	3,972			$	64			Discounted cash flow		Estimated auction price	$	(5.24	)	$	6.95
FTRs at Dec. 31, 2013	$	9,020			$	382			Discounted cash flow		Estimated auction price	$	(4.88	)	$	33.75
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 discounted 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 are situations in which there is little, if any, market activity for the asset or liability at the measurement date and therefore estimated prices are used in the discounted cash flow approach.
The assets and liabilities reported at fair value are grouped into classes based on the underlying nature and risks associated with the individual asset or liability.
At March 31, 2014, 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 the Cleco Condensed Consolidated Balance Sheet in cash and cash equivalents, current restricted cash and cash equivalents, and non-current restricted cash and cash equivalents of $12.2 million, $3.9 million, and $14.4 million, respectively, at March 31, 2014. At Cleco Power, the institutional money market funds were reported on the Condensed Consolidated Balance Sheet in cash and cash equivalents, current restricted cash and cash equivalents, and non-current restricted cash and cash equivalents of $5.9 million, $3.9 million, and $14.4 million, respectively, at March 31, 2014. 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 in order 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.
The commercial paper, municipal bonds, corporate bonds, and federal agency mortgage-backed securities were reported on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets in restricted investments in the amount of $1.5 million, $9.8 million, $0.5 million and $1.0 million at December 31, 2013, respectively. During the first quarter of 2014, Cleco ended its relationship with its outside investment manager and liquidated all holdings in these restricted investments. The Level 2 commercial paper, municipal bonds, corporate bonds, and federal agency mortgage-backed securities consisted of a single class. In order to maximize income, meet the requirements established by the LPSC for the restricted reserve fund, and maintain safety and liquidity, restricted cash and cash equivalents were invested in short-term, fixed-income debt instruments. The risks associated with this class were counterparty risk of the outside investment manager and risk of price volatility associated with the commercial paper, municipal bonds, corporate bonds, and federal agency mortgage-backed securities. Quarterly, Cleco received reports from the trustee for the investment manager which provided the fair value measurement. Cleco performed an evaluation of those reports to verify the fair value of the securities.
The Level 3 FTRs consist of a single class. As part of Cleco Power’s integration into MISO, Cleco Power was awarded FTRs in November 2013. Cleco Power also purchased FTRs in auctions facilitated by MISO. Cleco Power’s FTRs were priced using MISO’s monthly estimated auction prices. The monthly estimated auction prices are discounted to net present value to determine fair value. 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. For more information about FTRs, see “—Derivatives and Hedging.”
The Level 2 long-term debt liability consists of a single class. In order to fund capital requirements, Cleco issues long-term, fixed and variable rate 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 that issued the debt.
During the three months ended March 31, 2014, and the year ended December 31, 2013, Cleco did not experience any transfers between levels.
Restricted Investments
In September 2007, the LPSC authorized the funding and securitization of a $50.0 million reserve for Cleco Power’s future storm costs. On July 1, 2012, Cleco Power transferred $13.0 million of the related restricted cash and cash equivalents to an outside investment manager. Investments made by the investment manager were restricted to the criteria established by management in Cleco Power’s guidelines for short-term investments. During the first quarter of 2014, Cleco ended its relationship with this outside investment manager and liquidated all holdings in these restricted investments.
The cash and cash equivalents were reflected in Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at December 31, 2013, as restricted cash and cash equivalents at their approximate fair value because of their short-term nature.
The debt securities were recorded at fair value on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at December 31, 2013, as restricted investments. The investments in debt securities included municipal bonds, corporate bonds, federal agency mortgage-backed securities, and commercial paper with original maturity dates of more than three months and were classified as available-for-sale securities and reported at fair value. Because Cleco Power’s investment strategy for these investments was within the requirements established by the LPSC for the restricted reserve fund, realized and unrealized gains and losses, interest income, investment management fees, and custody fees were recorded directly to Cleco Power’s restricted storm reserve rather than in earnings or OCI. As a result, no amounts were recorded to OCI for these investments. The unrealized gains and losses on Cleco Power’s debt securities at December 31, 2013, were caused by interest rate movements.
The following table provides a reconciliation of Cleco Power’s available-for-sale debt securities from amortized cost to fair value at December 31, 2013:
	AT DEC. 31, 2013
(THOUSANDS)	AMORTIZED				TOTAL				TOTAL			FAIR VALUE
	COST				UNREALIZED GAINS (1)				UNREALIZED
									LOSSES (1)
Municipal bonds	$	9,838			$	8			$	15		$	9,831
Corporate bonds	513				2				—			515
Federal agency mortgage-backed securities	1,000				—				—			1,000
Commercial paper	1,483				—				—			1,483
Total available-for-sale debt securities	$	12,834			$	10			$	15		$	12,829
(1)  Unrealized gains and losses are recorded to the restricted storm reserve.
For the three months ended March 31, 2014, Cleco Power recognized less than $0.1 million of realized gains as a result of the portfolio being liquidated. Realized gains and losses were determined on a specific identification basis.
Derivatives and Hedging
The authoritative guidance on derivatives and hedging requires entities to provide transparent disclosures about a company’s derivative activities and how the related hedged items affect a company’s financial position, financial performance, and cash flows. Cleco is required to provide qualitative and quantitative disclosures about derivative fair value, gains and losses, and credit-risk-related contingent features in derivative agreements.
Commodity Contracts
The following table presents the fair values of derivative instruments and their respective line items as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2014 and December 31, 2013:
	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
(THOUSANDS)	BALANCE SHEET LINE ITEM		AT MAR. 31, 2014				AT DEC. 31, 2013
Commodity contracts
FTRs:
Current	Energy risk management assets		$	3,972			$	9,020
Current	Energy risk management liabilities		64				382
Total			$	3,908			$	8,638
The following table presents the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2014:
	FOR THE THREE MONTHS ENDED MAR. 31,
			2014
(THOUSANDS)	DERIVATIVES LINE ITEM		AMOUNT OF GAIN/(LOSS)
			RECOGNIZED IN
			INCOME ON
			DERIVATIVES
Commodity contracts
FTRs	Electric operations		$	3,965
FTRs	Power purchased for utility customers		(1,115		)
Total			$	2,850
At March 31, 2014 and December 31, 2013, Cleco Power had no open positions hedged for natural gas.
As part of the integration into MISO, Cleco Power was awarded FTRs in November 2013. Cleco Power also purchased FTRs in auctions facilitated by MISO. FTRs provide a financial hedge to manage the risk of congestion cost in the Day-Ahead Energy Market. FTRs represent rights to congestion credits or charges along a transmission path during a given time frame for a certain MW quantity. At March 31, 2014 and December 31, 2013, Cleco Power had 3.8 million MWh and 6.8 million MWh, respectively, of FTRs hedged.
Interest Rate Derivatives
In November 2011, Cleco Power entered into a pay fixed/receive variable forward starting interest rate swap contract in order to mitigate the interest rate exposure on coupon payments related to the remaining $50.0 million fixed-rate forecasted debt issuance. The forward starting interest rate swap had a spot 30-year all-in swap rate of 3.05%, notional amount of $50.0 million, with the pricing date of May 14, 2013, or the issuance of the notes, whichever was earlier. The forward starting interest rate swap met the criteria of a cash flow hedge under the authoritative guidance as it related to derivatives and hedging and was carried on the balance sheet at its fair value.
During the first quarter of 2013, Cleco determined that the forward starting interest rate swap ceased to be highly effective in offsetting changes in the cash flows of the forecasted coupon payments and discontinued hedge accounting prospectively. In May 2013, upon pricing of the 2008 Series B GO Zone bonds, Cleco Power settled the forward starting interest rate swap at a loss of $3.3 million. Of this amount, Cleco Power deferred $2.9 million as a regulatory asset and recognized $0.4 million in OCI. In May 2013, Cleco Power began amortizing these losses over the 25-year term of the related debt.
The following table presents the effect of derivatives designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2014 and 2013.
	FOR THE THREE MONTHS ENDED MAR. 31,
	2014								2013
(THOUSANDS)	AMOUNT				AMOUNT OF LOSS				AMOUNT			AMOUNT OF LOSS
	OF GAIN				RECLASSIFIED FROM				OF GAIN			RECLASSIFIED FROM
	RECOGNIZED				ACCUMULATED OCI				RECOGNIZED			ACCUMULATED OCI
	IN OCI				INTO INCOME				IN OCI			INTO INCOME
					(EFFECTIVE PORTION)							(EFFECTIVE PORTION)
Interest rate	$	—			$	(86	)*		$	1,762		$	(20	)*
derivatives (1)
* The loss reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.
(1) During the three months ended March 31, 2013, Cleco recorded ineffectiveness and losses related to the interest rate derivatives as a regulatory asset of $0.4 million.
At March 31, 2014, Cleco Power expected $0.3 million of the effective portion of deferred net losses related to interest rate derivatives to be reclassed from accumulated OCI to interest charges over the next 12 months.

Debt

Debt	3 Months Ended
	Mar. 31, 2014
Debt Disclosure [Abstract]	'
Debt	'
	Note 5 — Debt
	Short-term Debt
	At March 31, 2014 and December 31, 2013, Cleco and Cleco Power had no short-term debt outstanding.
	Long-term Debt
	At March 31, 2014, Cleco’s long-term debt outstanding was $1.31 billion, of which $17.7 million was due within one year. The long-term debt due within one year at March 31, 2014, represents $15.4 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $2.3 million of capital lease payments.
	For Cleco, long-term debt decreased $18.0 million from December 31, 2013, primarily due to a $10.0 million net reduction in credit facility draws, a $7.6 million scheduled Cleco Katrina/Rita storm recovery bond principal payment made in March 2014, and a $0.5 million decrease in capital lease obligations. These decreases were partially offset by debt discount amortizations of $0.1 million.
	At March 31, 2014, Cleco Power’s long-term debt outstanding was $1.30 billion of which $17.7 million was due within one year. The long-term debt due within one year at March 31, 2014, represents $15.4 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $2.3 million of capital lease payments.
	For Cleco Power, long-term debt decreased $28.0 million from December 31, 2013, primarily due to a $20.0 million repayment of credit facility draws, a $7.6 million scheduled Cleco Katrina/Rita storm recovery bond principal payment made in March 2014, and a $0.5 million decrease in capital lease obligations. These decreases were partially offset by debt discount amortizations of $0.1 million.
	Credit Facilities
	At March 31, 2014, Cleco Corporation had $15.0 million of borrowings outstanding under its existing $250.0 million credit facility and Cleco Power had no borrowings outstanding under its existing $300.0 million credit facility. In December 2013, Cleco Power provided a $1.0 million letter of credit to MISO pursuant to the credit requirements of FTRs. This letter of credit is automatically renewed each year and reduces Cleco Power’s credit facility capacity. On April 8, 2014, Cleco Power increased the letter of credit to $2.0 million.

Pension_Plan_and_Employee_Bene

Pension Plan and Employee Benefits	3 Months Ended
	Mar. 31, 2014
Compensation and Retirement Disclosure [Abstract]	'
Pension Plan and Employee Benefits	'
	Note 6 — Pension Plan and Employee Benefits
	Pension Plan and Other Benefits Plan
	Most 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 does not expect to make any required or discretionary contributions to the pension plan in 2014. In January 2013, Cleco Power made $34.0 million in discretionary contributions to the pension plan designated for the 2012 plan year. The required contributions are driven by liability funding target percentages set by law which could cause the required contributions to be uneven among the years. The ultimate amount and timing of the contributions may be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator.
	Cleco’s retirees and their dependents may be eligible to receive medical, dental, vision, and life insurance benefits (other benefits). Cleco recognizes the expected cost of these other benefits during the periods in which the benefits are earned.
	The components of net periodic pension and other benefit cost for the three months ended March 31, 2014 and 2013, are as follows:
		PENSION BENEFITS						OTHER BENEFITS
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013			2014		2013
	Components of periodic benefit cost:
	Service cost	$	2,005		$	2,484		$	405	$	314
	Interest cost	4,930			4,437			463		481
	Expected return on plan assets	(6,083		)	(5,764		)	—		—
	Amortizations:
	Transition obligation	—			—			5		4
	Prior period service cost (credit)	(18		)	(18		)	30		—
	Net loss	1,713			3,373			177		318
	Net periodic benefit cost	$	2,547		$	4,512		$	1,080	$	1,117
	Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three months ended March 31, 2014 and 2013, was $0.5 million and $0.6 million, respectively.
	Cleco Corporation 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 current portion of the other benefits liability for Cleco at March 31, 2014 and December 31, 2013 was $3.5 million. The current portion of the other benefits liability for Cleco Power at March 31, 2014 and December 31, 2013 was $3.2 million. The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2014 and 2013, was $0.9 million and $1.0 million, respectively.
	SERP
	Certain Cleco officers are covered by SERP. SERP is a non-qualified, non-contributory, defined benefit pension plan. Benefits under the plan reflect an employee’s years of service, age at retirement, and the sum of the highest base salary paid out of the last five calendar years plus the average of the three highest cash bonuses paid during the 60 months prior to retirement, reduced by benefits received from any other defined benefit pension plan, SERP Plan, or Cleco contributions under the enhanced 401(k) Plan to the extent such contributions exceed the limits of the 401(k) Plan. 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. 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. No contributions to SERP were made during the three months ended March 31, 2014 or 2013. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator. The components of net periodic SERP benefit cost for the three months ended March 31, 2014 and 2013, are as follows:
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013
	Components of periodic benefit cost:
	Service cost	$	468		$	506
	Interest cost	725			678
	Amortizations:
	Prior period service cost	12			14
	Net loss	385			536
	Net periodic benefit cost	$	1,590		$	1,734
	The SERP liabilities are reported on the individual subsidiaries’ financial statements. The current portion of the SERP liability for Cleco at March 31, 2014 and December 31, 2013 was $2.7 million. The current portion of the SERP liability for Cleco Power at March 31, 2014 and December 31, 2013 was $0.9 million and $0.7 million, respectively. The expense related to SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income was $0.3 million for the three months ended March 31, 2014, compared to $0.4 million for the same period in 2013.
	401(k) Plan
	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 Cleco Corporation stock or cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Plan participants are allowed to choose whether to have dividends on Cleco Corporation common stock distributed in cash or reinvested in additional shares of Cleco Corporation common stock. Participation in the Plan is voluntary and active Cleco employees are eligible to participate. Cleco’s 401(k) Plan expense for the three months ended March 31, 2014 and 2013 is as follows:
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013
	401(k) Plan expense	$	1,369		$	1,279
	Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three months ended March 31, 2014 and 2013, was $0.3 million and $0.4 million, respectively.

Income_Taxes

Income Taxes	3 Months Ended
	Mar. 31, 2014
Income Tax Disclosure [Abstract]	'
Income Taxes	'
	Note 7 — Income Taxes
	The following table summarizes the effective income tax rates for Cleco and Cleco Power for the three month periods ended March 31, 2014 and 2013.
		FOR THE THREE MONTHS ENDED MAR. 31,
		2014		2013
	Cleco	34.5	%	32.5	%
	Cleco Power	35.1	%	33.9	%
	Effective Tax Rates
	For the three months ended March 31, 2014 and 2013, the effective income tax rate for Cleco was different than the federal statutory rate due to permanent tax deductions, the flowthrough of tax benefits associated with AFUDC equity, tax benefits delivered from Cleco’s investment in the NMTC Fund, and state tax expense.
	For the three months ended March 31, 2014 and 2013, the effective income tax rate for Cleco Power was different than the federal statutory rate due to permanent tax deductions, the flowthrough of tax benefits associated with AFUDC equity, and state tax expense.
	Valuation Allowance
	Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a tax benefit will not be realized. As of March 31, 2014 and December 31, 2013, Cleco had a deferred tax asset resulting from NMTC carryforwards of $96.5 million and $95.4 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 March 31, 2014, Cleco had a net operating loss carryforward primarily related to a tax accounting method change for bonus depreciation associated with Madison Unit 3. Cleco considers it more likely than not that these income tax losses generated will be utilized to reduce future income taxes, and Cleco expects to utilize the entire net operating loss carryforward within the statutory deadlines.
	Uncertain Tax Positions
	Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. The total amounts of interest payable and interest expense related to uncertain tax positions, as reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets and Statements of Income, are shown in the following tables.
	(THOUSANDS)	AT MAR. 31, 2014			AT DEC. 31, 2013
	Interest payable
	Cleco	$	96		$	88
	Cleco Power	$	12		$	11
	The interest payable reflects the amount of interest anticipated to be paid to taxing authorities. These amounts do not include any offset for amounts that may be recovered from customers under existing rate orders. The amounts expected to be recoverable from Cleco Power’s customers under existing rate orders at March 31, 2014 and December 31, 2013, are $8.7 million and $8.4 million, respectively.
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013
	Interest charges
	Cleco	$	30		$	(69	)
	Cleco Power	$	1		$	121
	The interest charges reflect the amount of interest anticipated to be paid to or received from taxing authorities. These amounts do not include any offset for the 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 at March 31, 2014 and March 31, 2013, increased by $0.6 million and $0.7 million, respectively.
	The federal income tax years that remain subject to examination by the IRS are 2010 through 2012. The Louisiana state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2005 through 2012. At December 31, 2012, Cleco had $60.4 million deposited with the IRS, of which Cleco received a refund of tax and interest in January 2013 from the IRS of $42.3 million relating to tax years 2001 through 2008.
	Cleco is currently under audit by the IRS for the years 2010 through 2012. During 2013, Cleco increased its liability for uncertain tax positions. In addition, Cleco reclassified all uncertain tax positions to current from noncurrent as it expects to settle all outstanding audits within the next 12 months. Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of March 31, 2014, could decrease by a maximum of $4.6 million for Cleco and the balance for Cleco Power would be unchanged in the next 12 months as a result of reaching settlements with the IRS and state tax authorities. The settlements 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 expense. For the three months ended March 31, 2014 and 2013, the amount of penalties recognized was immaterial.

Disclosures_about_Segments

Disclosures about Segments	3 Months Ended
	Mar. 31, 2014
Segment Reporting [Abstract]	'
Disclosures about Segments	'
	Note 8 — Disclosures about Segments
	Cleco’s reportable segments are based on its method of internal reporting, which disaggregates business units by its first-tier subsidiary. Cleco’s reportable segments are Cleco Power and Midstream. On March 15, 2014, the Coughlin generating assets were transferred from Midstream to Cleco Power. Due to this transfer, there will be minimal operating activity and operating earnings at Midstream in future periods. For more information, see “— Note 14 — Coughlin Transfer.” The holding company, a shared services subsidiary, two transmission interconnection facility subsidiaries, and an investment subsidiary are shown as Other in the following tables.
	Each reportable segment engages in business activities from which it earns revenue and incurs expenses. Segment managers report periodically to Cleco’s Chief Executive Officer (the chief operating decision-maker) with discrete financial information and, at least quarterly, present discrete financial information to Cleco Corporation’s Board of Directors. Each reportable segment prepared budgets for 2014 that were presented to and approved by Cleco Corporation’s Board of Directors.
	The financial results of Cleco’s segments are presented on an accrual basis. Management evaluates the performance of its segments and allocates resources to them 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. Prior to March 15, 2014, these intercompany transactions related primarily to the power purchase agreement between Cleco Power and Evangeline that began in 2012 and joint and common administrative support services provided by Support Group. Subsequent to March 15, 2014, these intercompany transactions relate primarily to joint and common administrative support services provided by Support Group.
	SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MAR. 31,
	2014 (THOUSANDS)	CLECO POWER			MIDSTREAM			OTHER			ELIMINATIONS			CONSOLIDATED
	Revenue
	Electric operations	$	269,759		$	—		$	—		$	—		$	269,759
	Tolling operations	—			5,467			—			(5,467		)	—
	Other operations	14,272			—			541			1			14,814
	Electric customer credits	(186		)	—			—			—			(186		)
	Affiliate revenue	335			—			13,192			(13,527		)	—
	Operating revenue, net	$	284,180		$	5,467		$	13,733		$	(18,993	)	$	284,387
	Depreciation	$	40,203		$	1,269		$	269		$	—		$	41,741
	Interest charges	$	19,758		$	13		$	362		$	135		$	20,268
	Interest income	$	602		$	—		$	(133	)	$	133		$	602
	Federal and state income tax expense (benefit)	$	14,210		$	(81	)	$	(451	)	$	—		$	13,678
	Net income (loss)	$	26,307		$	(130	)	$	(252	)	$	(1	)	$	25,924
	Additions to (reductions in) long-lived assets	$	234,153		$	(176,293	)	$	196		$	—		$	58,056
	Equity investment in investees	$	14,532		$	—		$	8		$	—		$	14,540
	Total segment assets	$	4,091,584		$	51,180		$	66,632		$	(26,399	)	$	4,182,997
	2013 (THOUSANDS)	CLECO POWER			MIDSTREAM			OTHER			ELIMINATIONS			CONSOLIDATED
	Revenue
	Electric operations	$	229,425		$	—		$	—		$	—		$	229,425
	Tolling operations	—			4,837			—			(4,837		)	—
	Other operations	11,038			1			504			—			11,543
	Electric customer credits	(21		)	—			—			—			(21		)
	Affiliate revenue	336			—			11,925			(12,261		)	$	—
	Operating revenue, net	$	240,778		$	4,838		$	12,429		$	(17,098	)	$	240,947
	Depreciation	$	32,330		$	1,500		$	203		$	(1	)	$	34,032
	Interest charges	$	21,349		$	(239	)	$	163		$	183		$	21,456
	Interest income	$	198		$	—		$	(180	)	$	183		$	201
	Federal and state income tax expense (benefit)	$	14,238		$	(840	)	$	(317	)	$	—		$	13,081
	Net income (loss)	$	27,793		$	(1,334	)	$	674		$	—		$	27,133
	Additions to long-lived assets	$	41,558		$	1,829		$	561		$	—		$	43,948
	Equity investment in investees (1)	$	14,532		$	—		$	8		$	—		$	14,540
	Total segment assets  (1)	$	3,943,712		$	225,832		$	88,234		$	(42,516	)	$	4,215,262
	(1) Balances as of December 31, 2013

Electric_Customer_Credits

Electric Customer Credits	3 Months Ended
	Mar. 31, 2014
Regulated Operations [Abstract]	'
Electric Customer Credits	'
	Note 9 — Electric Customer Credits
	The current amount of Cleco Power’s annual retail earnings is subject to the terms of an FRP established by the LPSC effective February 12, 2010. The FRP allows Cleco Power the opportunity to earn a target return on equity of 10.7%, including returning to retail customers 60% of retail earnings between 11.3% and 12.3% and all retail earnings over 12.3%. The amount of credits due customers, if any, is determined by Cleco Power and the LPSC annually. The ultimate amount of any customer refund is subject to LPSC approval. Cleco Power must file annual monitoring reports no later than October 31 for the 12-month period ending June 30.
	On October 31, 2013, Cleco Power filed its monitoring report for the 12 months ended June 30, 2013 which indicated that $2.2 million was due to be returned to customers. On April 9, 2014, the LPSC Staff filed their report indicating agreement with Cleco Power’s refund calculation for the12 months ended June 30, 2013. Cleco Power anticipates approval of the LPSC Staff’s report in the second quarter of 2014 and expects to issue refunds for this filing on customers’ bills in the third quarter of 2014. The accrual for estimated electric customer credits reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2014 and December 31, 2013, was $3.7 million and $3.5 million, respectively.
	In April 2013, Cleco Power filed an application with the LPSC to extend its current FRP and seek rate recovery of Coughlin. After evaluating various rate options, on March 26, 2014, Cleco Power filed supplemental information supporting its request in this application. The docket is currently in the discovery phase. Cleco Power expects LPSC action on this request by the end of the second quarter of 2014.

Variable_Interest_Entities

Variable Interest Entities	3 Months Ended
	Mar. 31, 2014
Variable Interest Entities [Abstract]	'
Variable Interest Entities	'
	Note 10 — Variable Interest Entities
	Cleco reports its investments in VIEs in accordance with the authoritative guidance. Cleco and Cleco Power report the investment in Oxbow on the equity method of accounting. Under the equity method, the assets and liabilities of this entity are reported as equity investment in investees on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of this entity are netted and reported as equity income or loss from investees on Cleco and Cleco Power’s Condensed Consolidated Statements of Income.
	Equity Method VIEs
	Equity investment in investees at March 31, 2014, primarily represents Cleco Power’s $14.5 million investment in Oxbow. Equity investments that are less than 100% owned by Diversified Lands represented less than $0.1 million of the total balance.
	Oxbow
	Oxbow is owned 50% by Cleco Power and 50% by SWEPCO and is accounted for as an equity method investment. Cleco Power is not the primary beneficiary because it shares the power to control Oxbow’s significant activities with SWEPCO. Cleco’s current assessment of its maximum exposure to loss related to Oxbow at March 31, 2014, consisted of its equity investment of $14.5 million. The following table presents the components of Cleco Power’s equity investment in Oxbow.
	INCEPTION TO DATE (THOUSANDS)	AT MAR. 31, 2014		AT DEC. 31, 2013
	Purchase price	$	12,873	$	12,873
	Cash contributions	1,659		1,659
	Total equity investment in investee	$	14,532	$	14,532
	The following table compares the carrying amount of Oxbow’s assets and liabilities with Cleco’s maximum exposure to loss related to its investment in Oxbow.
	(THOUSANDS)	AT MAR. 31, 2014		AT DEC. 31, 2013
	Oxbow’s net assets/liabilities	$	29,065	$	29,065
	Cleco Power’s 50% equity	$	14,532	$	14,532
	Cleco’s maximum exposure to loss	$	14,532	$	14,532
	The following tables contain summarized financial information for Oxbow.
	(THOUSANDS)	AT MAR. 31, 2014		AT DEC. 31, 2013
	Current assets	$	2,303	$	2,289
	Property, plant, and equipment, net	22,587		22,611
	Other assets	4,248		4,256
	Total assets	$	29,138	$	29,156
	Current liabilities	$	61	$	91
	Other liabilities	12		—
	Partners’ capital	29,065		29,065
	Total liabilities and partners’ capital	$	29,138	$	29,156
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014		2013
	Operating revenue	$	585	$	429
	Operating expenses	585		429
	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.

Litigation_Other_Commitments_a

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	3 Months Ended
	Mar. 31, 2014
Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees [Abstract]	'
Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	'
	Note 11 — 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 CERCLA (also known as the Superfund statute). CERCLA establishes several classes of PRPs for a contaminated site, and imposes strict, joint, and several liability on those PRPs for the cost of response to the contamination. The special notice requested that Cleco Corporation and Cleco Power, along with many other listed PRPs, enter into negotiations with the EPA for the performance of an RI/FS at an area known as the Devil’s Swamp Lake site just northwest of Baton Rouge, Louisiana. The EPA identified Cleco as one of many companies that was sending polychlorinated biphenyl wastes for disposal to the site. The Devil’s Swamp Lake site has been proposed to be added to the National Priorities List based on the release of PCBs to fisheries and wetlands located on the site, but no final determination has been made. The PRPs began discussing a potential proposal to the EPA in February 2008. The EPA issued a Unilateral Administrative Order to PRP’s Clean Harbors, Inc. and Baton Rouge Disposal to Conduct an RI/FS on December 3, 2009. The Tier 1 part of the study was complete in June 2012. Field activities for the Tier 2 investigation were completed in July 2012. 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 facility site, if any, may be and whether or not this will have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.
	Discrimination Complaints
	In December 2009, a complaint was filed in the U.S. District Court for the Western District of Louisiana (the Court) on behalf of eight current employees and four former employees alleging that Cleco discriminated against each of them on the basis of race. Each was seeking various remedies provided under applicable statutes prohibiting racial discrimination in the workplace, and together, the plaintiffs requested monetary compensation exceeding $35.0 million. In July 2010, the plaintiffs moved to add an additional current employee alleging that Cleco had discriminated on the basis of race. The additional plaintiff sought compensation of no less than $2.5 million and became the thirteenth plaintiff. In April 2011, Cleco entered into a settlement with one of the current employees which resulted in a dismissal of one of the thirteen cases with prejudice. In September 2011, the Court ruled on Cleco’s summary judgment motions, with the end result that eleven of the twelve remaining plaintiffs had at least one claim remaining. In February 2013, the Court ruled on the second motion for summary judgment, filed by Cleco in March 2012, in each of the eleven cases and each such case was dismissed with prejudice. Appeals were filed in ten of the eleven dismissed cases to the United States Court of Appeals for the Fifth Circuit (the Fifth Circuit). In June 2013, the Fifth Circuit clerk dismissed the appeals of two of the current employees due to their failure to file a brief in support of their respective appeals. On various dates in August through November 2013, the Fifth Circuit affirmed the trial court judgments in favor of Cleco in seven of the eight remaining cases. On April 8, 2014, the Fifth Circuit affirmed the Court’s summary judgment dismissing the wrongful termination and other discrimination claims of the one remaining plaintiff, a former employee. Excepted from its ruling was one claim that the former employee alleged arising from a disciplinary warning Cleco issued to the former employee. The former employee who received the disciplinary warning served as one of Cleco’s human resources representatives. This one claim has been remanded to the Court for trial or other further proceedings.
	City of Opelousas
	In March 2010, a complaint was filed in the 27th Judicial District Court of St. Landry Parish, State of Louisiana, on behalf of three Cleco Power customers in Opelousas, Louisiana.  The complaint alleges that Cleco Power overcharged the plaintiffs by applying to customers in Opelousas the same retail rates as Cleco Power applies to all of its retail customers.  The plaintiffs claim that Cleco Power owes customers in Opelousas more than $30.0 million as a result of the alleged overcharges. The plaintiffs allege that Cleco Power should have established, solely for customers in Opelousas, retail rates that are separate and distinct from the retail rates that apply to other customers of Cleco Power and that Cleco Power should not collect from customers in Opelousas the storm surcharge approved by the LPSC following hurricanes Katrina and Rita. In April 2010, Cleco Power filed a petition with the LPSC appealing to its expertise in declaring that the ratepayers of Opelousas have been properly charged the rates that are applicable to Cleco Power’s retail customers and that no overcharges have been collected.
	In May 2010, a second class action lawsuit was filed in the 27th Judicial District Court for St. Landry Parish, State of Louisiana, repeating the allegations of the first complaint, which was submitted on behalf of 249 Opelousas residents. In January 2011, the presiding judge in the state court proceeding ruled that the jurisdiction to hear the two class actions resides in the state court and not with the LPSC as argued by both Cleco and the LPSC Staff. Both Cleco and the LPSC Staff appealed this ruling to the Third Circuit Court of Appeals for the State of Louisiana (Third Circuit). In September 2011, the Third Circuit denied both appeals. In October 2011, both Cleco and the LPSC appealed the Third Circuit’s ruling to the Louisiana Supreme Court. In February 2011, the administrative law judge (ALJ) in the LPSC proceeding ruled that the LPSC has jurisdiction to decide the claims raised by the class action plaintiffs. At its December 2011 Business and Executive Session, the LPSC adopted the ALJ’s recommendation that Cleco be granted summary judgment in its declaratory action finding that Cleco’s ratepayers in the City of Opelousas have been served under applicable rates and policies approved by the LPSC and Cleco’s Opelousas ratepayers have not been overcharged in connection with LPSC rates or ratemaking. In January 2012, the class action plaintiffs filed their appeal of such LPSC decision to the 19th Judicial District Court for East Baton Rouge Parish, State of Louisiana. In December 2012, the Louisiana Supreme Court issued its opinion accepting Cleco’s jurisdictional arguments and dismissed the state court claims. The only matter remaining is before the 19th Judicial District Court to review the LPSC ruling in Cleco’s favor that it had properly charged the ratepayers of Opelousas. In view of the uncertainty of the claims, management is not able to predict or give a reasonable estimate of the possible range of liability, if any, of these claims. However, if it is found that Cleco Power overcharged customers resulting in a refund, any such refund could have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.
	Other
	Cleco is involved in various litigation matters, including regulatory, environmental, and administrative proceedings before various courts, regulatory commissions, arbitrators, and governmental agencies regarding matters arising in the ordinary course of business. The liability Cleco may ultimately incur with respect to any one of these matters in the event of a negative outcome may be in excess of amounts currently accrued. Management regularly analyzes current information and, as of March 31, 2014, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters is approximately $10.5 million and has accrued this amount.
	Off-Balance Sheet Commitments
	Cleco Corporation and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Corporation’s subsidiaries and equity investees (affiliates). Cleco Corporation and Cleco Power have also agreed to contractual terms that require them to pay third parties if certain triggering events occur. These contractual terms generally are defined as guarantees in the authoritative guidance.
	Cleco Corporation 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 Corporation 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’s Condensed Consolidated Balance Sheets because management has determined that Cleco’s affiliates are able to perform these obligations under their contracts and that it is not probable that payments by Cleco will be required. Cleco’s off-balance sheet commitments as of March 31, 2014, are summarized in the following table and a discussion of the off-balance sheet commitments follows the table. The discussion should be read in conjunction with the table to understand the impact of the off-balance sheet commitments on Cleco’s financial condition.
		AT MAR. 31, 2014
	(THOUSANDS)	FACE AMOUNT
	Cleco Corporation
	Guarantee issued to Entergy Mississippi on behalf of Attala	$	500
	Cleco Power
	Obligations under standby letter of credit issued to the Louisiana Department of Labor	3,725
	Obligations under standby letter of credit issued to MISO	1,000
	Total	$	5,225
	There were no reductions against the face amount for any of these commitments.
	In January 2006, Cleco Corporation provided a $0.5 million guarantee to Entergy Mississippi for Attala’s obligations under the Interconnection Agreement. This guarantee will be effective until obligations are performed or extinguished.
	The State of Louisiana allows employers of certain financial net worth to self-insure their workers’ compensation benefits. Cleco Power has a certificate of self-insurance from the Louisiana Office of Workers’ Compensation and is required to post a $3.7 million letter of credit, an amount equal to 110% of the average losses over the previous three years, as surety.
	In December 2013, Cleco Power provided a $1.0 million letter of credit to MISO pursuant to the credit requirements of FTRs. On April 8, 2014, Cleco Power increased the letter of credit to $2.0 million. The letter of credit is automatically renewed each year and reduces Cleco Power’s credit facility capacity.
	Cleco Corporation provided indemnifications to Cleco Power as a result of the transfer of Coughlin to Cleco Power on March 15, 2014. Cleco Power also provided indemnifications to Cleco Corporation and Evangeline as a result of the transfer of Coughlin to Cleco Power. The maximum amount of the potential payment to Cleco Power, Cleco Corporation, and Evangeline for their respective indemnifications is $40.0 million, except for indemnifications relating to the fundamental organizational structure of Cleco Corporation and Evangeline and of Cleco Power, respectively, of which the maximum amount is $400.0 million.
	Disclosures about Guarantees
	Cleco Corporation provided a limited guarantee and an indemnification to Entergy Louisiana and Entergy Gulf States for Perryville’s performance, indemnity, representation, and warranty obligations under the Sale Agreement, the Power Purchase Agreement, and other ancillary agreements related to the sale of the Perryville facility in 2004. This is a continuing guarantee and all obligations of Cleco Corporation shall continue until the guaranteed obligations have been fully performed or otherwise extinguished. The discounted probability-weighted liability under the guarantees and indemnifications recognized on Cleco’s Condensed Consolidated Balance Sheet as of March 31, 2014, was $0.2 million. 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 the guarantee.
	In April 2011, Acadia completed its disposition of Acadia Unit 2 to Entergy Louisiana. Limited guarantees and indemnifications were provided to Entergy Louisiana and an indemnification liability of $21.8 million, which represents the fair value of these indemnifications was recorded on Cleco’s Condensed Consolidated Balance Sheet.
	The indemnification liabilities are reduced through expiration of the contractual life or through a reduction in the probability of a claim arising. The indemnification obligation is expected to have a term of three years. After the three-year period, a residual value of approximately $0.2 million will remain. At March 31, 2014, an indemnification liability of $0.9 million remained, which represents the risk of payment, as a contingent sale obligation recorded on Cleco’s Condensed Consolidated Balance Sheet. For the three months ended March 31, 2014 and 2013, no income was recognized. The maximum amount of the potential payment to Entergy Louisiana for the indemnifications is the purchase price of $298.8 million, except for the liabilities retained for which there is no maximum amount. Cleco Corporation is obligated to pay the same maximum amounts as Acadia if Acadia is unable to pay claims to Entergy Louisiana pursuant to the guarantee.
	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 they do not have sufficient funds or credit to pay. Any amounts paid on behalf of the miner would be credited by the lignite miner against future invoices for lignite delivered. At March 31, 2014, Cleco Power had a liability of $3.8 million related to the amended agreement. The maximum projected payment by Cleco Power under this guarantee is estimated to be $98.1 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 the guarantee.
	In its bylaws, Cleco Corporation has agreed to indemnify directors, officers, agents, and employees who are made a party to a pending or completed suit, arbitration, investigation, or other proceeding whether civil, criminal, investigative, or administrative, if the basis of inclusion arises as the result of acts conducted in the discharge of their official capacity. Cleco Corporation has purchased various insurance policies to reduce the risks associated with the indemnification. In its operating agreement, Cleco Power provides for the same indemnification as described above with respect to its managers, officers, agents, and employees.
	Generally, neither Cleco Corporation nor Cleco Power has recourse that would enable them to recover amounts paid under their guarantee or indemnification obligations. The one exception is the insurance contracts associated with the indemnification of directors, managers, officers, agents, and employees. There are no assets held as collateral for third parties that either Cleco Corporation or Cleco Power could obtain and liquidate to recover amounts paid pursuant to the guarantees or indemnification obligations.
	The following table summarizes the expected amount of commitment termination per period of off-balance sheet commitments and on-balance sheet guarantees discussed above.
								AT MAR. 31, 2014
				AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
	(THOUSANDS)	NET		LESS THAN		1-3 YEARS		3-5 YEARS		MORE
		AMOUNT		ONE YEAR						THAN
		COMMITTED								5 YEARS
	Off-balance sheet commitments	$	5,225	$	3,725	$	—	$	1,000	$	500
	On-balance sheet guarantees	4,906		900		—		—		4,006
	Total	$	10,131	$	4,625	$	—	$	1,000	$	4,506
	Other Commitments
	NMTC Fund
	In 2008, Cleco Corporation and US Bancorp Community Development Corporation (USBCDC) formed the NMTC Fund. Cleco 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 Corporation. In total, Cleco Corporation will contribute $283.6 million of equity contributions to the NMTC Fund and will receive at least $301.9 million in the form of tax credits, tax losses, capital gains/losses, earnings, and cash over the life of the investment, which ends in 2017. 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. The following table reflects remaining future equity contributions.
	(THOUSANDS)	CONTRIBUTION
	Nine months ending Dec. 31, 2014	$	36,252
	Years ending Dec. 31,
	2015	11,195
	2016	3,698
	2017	2,913
	Total	$	54,058
	Of the $54.1 million, $38.4 million is due to be paid within the next 12 months. Due to the right of offset, the investment and associated debt are presented on Cleco’s Condensed Consolidated Balance Sheet in the line item titled Tax credit fund investment, net. The amount of tax benefits delivered in excess of capital contributions as of March 31, 2014, was $62.4 million. The amount of tax benefits delivered but not utilized as of March 31, 2014, was $112.9 million and is reflected as a deferred tax asset.
	The equity contribution does not contain a stated rate of interest. Cleco Corporation has recorded the liability and investment at its calculated fair value within the framework of the authoritative guidance. In order to calculate the fair value, management used an imputed rate of interest assuming that Cleco Corporation obtained financing of a similar nature from a third party. The imputed interest rate was used in a net present value model in order to calculate the fair value of the remaining portion of the delayed equity contributions. The following table contains the disclosures required by the authoritative guidelines for equity investments with an imputed interest rate.
	(THOUSANDS)
	Equity contributions, imputed interest rate 6%
	Principal payment schedule above:	$	54,058
	Less:  unamortized discount	3,011
	Total	$	51,047
	The gross investment amortization expense will be recognized over a nine-year period, with four years remaining under the new amendment, using the cost method in accordance with the authoritative guidance for investments. 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.
	Other
Cleco has accrued for liabilities related to third parties and employee medical benefits. Cleco has also accrued additional taxes other than income taxes at the state and local level.
Risks and Uncertainties
Cleco Corporation
Cleco Corporation could be subject to possible adverse consequences if Cleco’s counterparties fail to perform their obligations or if Cleco Corporation or its affiliates are not in compliance with loan agreements or bond indentures.
Other
Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. If Cleco Corporation’s credit ratings were to be downgraded by Moody’s or S&P, Cleco Corporation would be required to pay additional fees and higher interest rates under its bank credit and 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 to be taken and Cleco’s financial condition could be materially adversely affected.
Cleco Power
Cleco Power began participating in the MISO market in December 2013. 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 will have higher LMP costs. Physical transmission constraints present in the MISO market could increase energy costs within Cleco Power’s pricing zone. Cleco Power receives FTRs to mitigate the transmission congestion risk. However, insufficient allocations or FTR costs due to negative congestion flows may result in an unexpected increase in energy costs to Cleco Power.
Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. Cleco Power pays fees and interest under its bank credit agreements based on the highest rating held. If Cleco Power’s credit ratings were to be downgraded by Moody’s or S&P, Cleco Power would be required to pay additional fees and higher interest rates under its bank credit agreements. Cleco Power’s collateral for derivatives is based on the lowest rating held. If Cleco Power’s credit ratings were to be downgraded by Moody’s or S&P, Cleco Power would be required to pay additional collateral for derivatives.

Affiliate_Transactions

Affiliate Transactions	3 Months Ended
	Mar. 31, 2014
Related Party Transactions [Abstract]	'
Affiliate Transactions	'
	Note 12 — Affiliate Transactions
	Cleco Power has affiliate balances that are payable to or due from its affiliates. The following table is a summary of those balances.
		AT MAR. 31, 2014				AT DEC. 31, 2013
	(THOUSANDS)	ACCOUNTS		ACCOUNTS		ACCOUNTS		ACCOUNTS
		RECEIVABLE		PAYABLE		RECEIVABLE		PAYABLE
	Cleco Corporation	$	1,773	$	712	$	379	$	389
	Support Group	853		6,203		634		5,972
	Midstream	265		11		27		1
	Evangeline	38		867		4		2,024
	Diversified Lands	1		—		1		—
	Other (1)	2		—		—		—
	Total	$	2,932	$	7,793	$	1,045	$	8,386
	(1) Represents Perryville and Attala

Accumulated_Other_Comprehensiv

Accumulated Other Comprehensive Loss	3 Months Ended
	Mar. 31, 2014
Equity [Abstract]	'
Comprehensive Income (Loss) Note	'
	Note 13 — 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 and amounts in parentheses indicate debits.
	Cleco
											FOR THE THREE MONTHS ENDED MAR. 31,
								2014									2013
	(THOUSANDS)	POSTRETIREMENT			NET LOSS			TOTAL			POSTRETIREMENT			NET LOSS			TOTAL
		BENEFIT NET LOSS			ON CASH FLOW			ACCUMULATED			BENEFIT NET LOSS			ON CASH FLOW			ACCUMULATED OTHER
					HEDGES			OTHER						HEDGES			COMPREHENSIVE
								COMPREHENSIVE									LOSS
								LOSS
	Balances at beginning of period	$	(19,725	)	$	(6,151	)	$	(25,876	)	$	(24,741	)	$	(7,629	)	$	(32,370	)
	Other comprehensive income before reclassifications:
	Net derivative gain	—			—			—			—			1,355			1,355
	Amounts reclassified from accumulated
	other comprehensive income:
	Amortization of postretirement benefit net loss	844			—			844			536			—			536
	Reclassification of net loss to interest charges	—			53			53			—			12			12
	Reclassification of ineffectiveness to regulatory asset	—			—			—			—			(30		)	(30		)
	Net current-period other comprehensive income	844			53			897			536			1,337			1,873
	Balances, Mar. 31,	$	(18,881	)	$	(6,098	)	$	(24,979	)	$	(24,205	)	$	(6,292	)	$	(30,497	)
	Cleco Power
											FOR THE THREE MONTHS ENDED MAR. 31,
								2014									2013
	(THOUSANDS)	POSTRETIREMENT			NET LOSS			TOTAL			POSTRETIREMENT			NET LOSS			TOTAL
		BENEFIT NET LOSS			ON CASH FLOW			ACCUMULATED			BENEFIT NET LOSS			ON CASH FLOW			ACCUMULATED OTHER
					HEDGES			OTHER						HEDGES			COMPREHENSIVE
								COMPREHENSIVE									LOSS
								LOSS
	Balances at beginning of period	$	(9,026	)	$	(6,151	)	$	(15,177	)	$	(12,792	)	$	(7,629	)	$	(20,421	)
	Other comprehensive income before reclassifications:
	Net derivative gain	—			—			—			—			1,355			1,355
	Amounts reclassified from accumulated
	other comprehensive income:
	Amortization of postretirement benefit net loss	525			—			525			251			—			251
	Reclassification of net loss to interest charges	—			53			53			—			12			12
	Reclassification of ineffectiveness to regulatory asset	—			—			—			—			(30		)	(30		)
	Net current-period other comprehensive income	525			53			578			251			1,337			1,588
	Balances, Mar. 31,	$	(8,501	)	$	(6,098	)	$	(14,599	)	$	(12,541	)	$	(6,292	)	$	(18,833	)

Coughlin_Transfer_Coughlin_Tra

Coughlin Transfer Coughlin Transfer	3 Months Ended
	Mar. 31, 2014
Related Party [Line Items]	'
Related Party Transactions Disclosure [Text Block]	'
	Note 14 — Coughlin Transfer
	In October 2012, Cleco Power announced that Evangeline was the winning bidder in Cleco Power’s 2012 Long-Term RFP, and in December 2012, Cleco Power and Evangeline executed definitive agreements to transfer ownership and control of Coughlin from Evangeline to Cleco Power. On March 15, 2014, Coughlin was transferred to Cleco Power with a net book value of $176.0 million. Cleco Power expects to finalize the rate treatment of Coughlin as part of its FRP extension proceeding before the LPSC, which is expected to be complete by the end of the second quarter of 2014.

Summary_of_Significant_Account1

Summary of Significant Accounting Policies (Policies)	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Principles of Consolidation, Policy	'
	The accompanying Condensed Consolidated Financial Statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.
Basis of Presentation, Policy	'
	The Condensed Consolidated Financial Statements of Cleco Corporation and Cleco Power have been prepared in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all of the information and notes required by GAAP for annual financial statements. The year-end Condensed Consolidated Balance Sheet data was derived from audited financial statements. Because the interim Condensed Consolidated Financial Statements and the accompanying notes do not include all of the information and notes required by GAAP for annual financial statements, the Condensed Consolidated Financial Statements and other information included in this quarterly report should be read in conjunction with the consolidated financial statements and accompanying notes in the Registrants’ Combined Annual Report on Form 10-K for the year ended December 31, 2013.
	These Condensed Consolidated Financial Statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly present the financial position and results of operations of Cleco. Amounts reported in Cleco’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, and other factors.
	In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates.
Property, Plant, and Equipment, Policy	'
	Property, plant, and equipment consists primarily of regulated utility generation and energy transmission 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.
Restricted Cash and Cash Equivalents, 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 corporate purposes.
Fair Value Measurements and Disclosures, Policy	'
	Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP.
	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 discounted 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 are situations in which there is little, if any, market activity for the asset or liability at the measurement date and therefore estimated prices are used in the discounted cash flow approach.
Risk Management, Policy	'
	Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes 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 applies the authoritative guidance as it relates to derivatives and hedging to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market. Generally, Cleco Power’s market risk-sensitive instruments and positions qualify for the normal-purchase, normal-sale exception to mark-to-market accounting because Cleco Power takes physical delivery and the instruments and positions are used to satisfy customer requirements.
	Cleco Power may also enter into 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 are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of energy risk management assets or liabilities. Such gain or loss is deferred as a component of deferred fuel assets or liabilities in accordance with regulatory policy. When these positions close, actual gains or losses will be included in the FAC and reflected on customers’ bills as a component of the fuel cost adjustment. As part of the integration into MISO, Cleco Power was awarded FTRs in November 2013. Cleco Power also purchased FTRs in auctions facilitated by MISO. FTRs provide a financial hedge to manage the risk of congestion cost in the Day-Ahead Energy Market. FTRs represent rights to congestion credits or charges along a transmission path during a given time frame for a certain MW quantity. At March 31, 2014, Cleco and Cleco Power's Condensed Consolidated Balance Sheets reflected open FTR positions of $4.0 million in Energy risk management assets and $0.1 million in Energy risk management liabilities, compared with $9.0 million in Energy risk management assets and $0.4 million in Energy risk management liabilities at December 31, 2013. There were no open natural gas positions at March 31, 2014 or December 31, 2013.
	Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, counterparty credit exposure, and counterparty concentration levels. Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and by 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 has entered into various contracts to mitigate the volatility in interest rate risk. These contracts include, but are not limited to, interest rate swaps and treasury rate locks.
Accounting for MISO Transactions, Policy	'
	Cleco Power participates in the energy market through MISO. MISO requires Cleco Power to submit hourly day-ahead, real time and FTR bids and offers for energy at locations across the MISO region. In each monthly reporting period, the hourly sale and purchase net amounts are aggregated and separately reported in Electric operations or Power purchased for utility customers on Cleco’s Condensed Consolidated Statements of Income.
Earnings Per Average Common Share, Policy	'
	Stock option grants are excluded from the computation of diluted earnings per share if the exercise price is higher than the average market price.
Stock-Based Compensation, Policy	'
	At March 31, 2014, Cleco had two stock-based compensation plans, the ESPP and the LTICP. Substantially all employees, excluding officers and general managers, may choose to participate in the ESPP and purchase a limited amount of common stock at a discount through a stock option agreement. Options or restricted shares of stock, known as non-vested stock as defined by the authoritative guidance on stock-based compensation, common stock equivalents, and stock appreciation rights may be granted to certain officers, key employees, or directors of Cleco Corporation and its subsidiaries pursuant to the LTICP.
Common Stock Repurchase Program, Policy	'
	In January 2011, Cleco Corporation’s Board of Directors approved the implementation of a new common stock repurchase program. This program authorizes management to repurchase, from time to time, shares of common stock so that Cleco’s diluted average shares of common stock outstanding remain approximately equal to its diluted average shares of common stock outstanding for 2010. Under this program, purchases may be made on a discretionary basis at times and in amounts as determined by management, subject to market conditions, legal requirements and other factors. Purchases under the program will not be announced in advance and may be made in the open market or through privately negotiated transactions.
New Accounting Pronouncements, Policy	'
	The Registrants adopted, or will adopt, the recent authoritative guidance listed below on their respective effective dates.
	In February 2013, FASB revised the disclosure requirements related to items reclassified out of accumulated other comprehensive income. This guidance is intended to improve the transparency of changes in OCI. This revision is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. Cleco adopted the revisions to this amendment during the first quarter of 2013. The adoption of this revision did not have an impact on the financial condition, results of operations, or cash flows of the Registrants because it relates to disclosures. For more information on items reclassified out of accumulated other comprehensive income, see Note 13 — “Accumulated Other Comprehensive Loss.”
	In February 2013, FASB issued guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. The adoption of this guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance did not have an impact on the financial condition, results of operations, or cash flows of the Registrants.
	In April 2013, FASB issued guidance on applying the liquidation basis of accounting and the related disclosure requirements. Under this accounting standards update, an entity must use the liquidation basis of accounting to present its financial statements when it determines that liquidation is imminent, unless the liquidation is the same as that under the plan specified in an entity's governing documents created at its inception. The adoption of this standard is effective for entities that determine liquidation is imminent during annual reporting periods beginning after December 15, 2013, and interim reporting periods therein. The adoption of this guidance did not have an impact on the financial condition, results of operations, or cash flows of the Registrants.
	In July 2013, FASB amended the income tax guidance to provide for the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. The adoption of this guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance did not have an impact on the financial condition, results of operations, or cash flows of the Registrants.
	In January 2014, FASB amended the accounting guidance for investments in qualified affordable housing projects. This guidance modifies the conditions that must be met to present the pretax effects and related tax benefits of such investments as a component of income taxes. The adoption of this guidance is effective for annual periods and interim reporting periods within those annual periods, beginning after December 31, 2014. Management is currently evaluating the effect the adoption of this guidance will have on the financial condition, results of operations, or cash flows of the Registrants.
	In January 2014, FASB amended the accounting guidance for service concession arrangements. This guidance states that certain service concession arrangements with public-sector grantors are not within the scope of lease accounting. Operating entities entering into these arrangements should not recognize the related infrastructure as its property, plant and equipment and should apply other accounting guidance. The adoption of this guidance is effective for interim periods beginning after December 15, 2014. Management is currently evaluating the effect the adoption of this guidance will have on the financial condition, results of operations, or cash flows of the Registrants.
	In April 2014, FASB amended the accounting guidance for the reporting of discontinued operations. These amendments improve the definition of discontinued operations by limiting discontinued operations reporting to disposals of components of an entity that represent strategic shifts that have or will have a major effect on an entity’s operations and financial results. This guidance also requires additional disclosures about discontinued operations. The adoption of this guidance is effective for all disposals (or classifications as held for sale) of components of an entity that occur within annual periods beginning on or after December 15, 2014, and interim periods within those years. The adoption of this guidance is not expected to have an effect on the financial condition, results of operations, or cash flows of the Registrants.
Public Utilities, Policy	'
	Cleco Power follows the authoritative guidance on regulated operations, which allows utilities to capitalize or defer certain costs based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process.
Marketable Securities, Available-for-sale Securities, Policy	'
	Because Cleco Power’s investment strategy for these investments was within the requirements established by the LPSC for the restricted reserve fund, realized and unrealized gains and losses, interest income, investment management fees, and custody fees were recorded directly to Cleco Power’s restricted storm reserve rather than in earnings or OCI. As a result, no amounts were recorded to OCI for these investments.
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.
	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 Cleco Corporation stock or cash. Cash contributions are invested in proportion to the participant’s voluntary contribution investment choices. Plan participants are allowed to choose whether to have dividends on Cleco Corporation common stock distributed in cash or reinvested in additional shares of Cleco Corporation common stock. Participation in the Plan is voluntary and active Cleco employees are eligible to participate
	Certain Cleco officers are covered by SERP. SERP is a non-qualified, non-contributory, defined benefit pension plan. Benefits under the plan reflect an employee’s years of service, age at retirement, and the sum of the highest base salary paid out of the last five calendar years plus the average of the three highest cash bonuses paid during the 60 months prior to retirement, reduced by benefits received from any other defined benefit pension plan, SERP Plan, or Cleco contributions under the enhanced 401(k) Plan to the extent such contributions exceed the limits of the 401(k) Plan.
	Most 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.
Income Tax, Policy	'
	Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense.
	Valuation allowances are recorded to reduce deferred tax assets when it is more likely than not that a tax benefit will not be realized.
	Cleco classifies income tax penalties as a component of other expense.
Segment Reporting, Policy	'
	The financial results of Cleco’s segments are presented on an accrual basis. Management evaluates the performance of its segments and allocates resources to them based on segment profit and the requirements to implement new strategic initiatives and projects to meet current business objectives.
Equity Method Investments, Policy	'
	Cleco reports its investments in VIEs in accordance with the authoritative guidance. Cleco and Cleco Power report the investment in Oxbow on the equity method of accounting. Under the equity method, the assets and liabilities of this entity are reported as equity investment in investees on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of this entity are netted and reported as equity income or loss from investees on Cleco and Cleco Power’s Condensed Consolidated Statements of Income.
Consolidation, Variable Interest Entity, Policy	'
	Oxbow is owned 50% by Cleco Power and 50% by SWEPCO and is accounted for as an equity method investment. Cleco Power is not the primary beneficiary because it shares the power to control Oxbow’s significant activities with SWEPCO.

Summary_of_Significant_Account2

Summary of Significant Accounting Policies (Tables)	3 Months Ended
	Mar. 31, 2014
Accounting Policies [Abstract]	'
Property, Plant, and Equipment	'
	Cleco’s property, plant, and equipment consisted of:
	(THOUSANDS)	AT MAR. 31, 2014			AT DEC. 31, 2013
	Regulated utility plants	$	4,311,221		$	4,052,774
	Other	15,096			273,748
	Total property, plant, and equipment	4,326,317			4,326,522
	Accumulated depreciation	(1,371,281		)	(1,351,223		)
	Net property, plant, and equipment	$	2,955,036		$	2,975,299
Restricted Cash and Cash Equivalents	'
	Cleco’s restricted cash and cash equivalents consisted of:
	(THOUSANDS)	AT MAR. 31, 2014			AT DEC. 31, 2013
	Diversified Lands’ mitigation escrow	$	21		$	21
	Cleco Katrina/Rita’s storm recovery bonds	3,893			8,986
	Cleco Power’s future storm restoration costs	14,025			4,726
	Cleco Power’s building renovation escrow	448			286
	Total restricted cash and cash equivalents	$	18,387		$	14,019
Earnings per Average Common Share	'
	The following tables show the calculation of basic and diluted earnings per share:
											FOR THE THREE MONTHS ENDED MAR. 31,
								2014							2013
	(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME			SHARES			PER SHARE			INCOME			SHARES	PER SHARE
								AMOUNT							AMOUNT
	Basic net income applicable to common stock	$	25,924		60,472,969			$	0.43		$	27,133		60,399,697	$	0.45
	Effect of dilutive securities
	Add:  restricted stock (LTICP)				240,618									267,704
	Diluted net income applicable to common stock	$	25,924		60,713,587			$	0.43		$	27,133		60,667,401	$	0.45
Stock-Based Compensation	'
	Cleco and Cleco Power reported pre-tax compensation expense for their share-based compensation plans as shown in the following table:
		CLECO CORPORATION							CLECO POWER
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013				2014			2013
	Equity classification
	Non-vested stock	$	1,922		$	1,428			$	426		$	331
	Total equity classification	$	1,922		$	1,428			$	426		$	331
	Liability classification
	Common stock	$	—		$	1			$	—		$	—
	equivalent units
	Total pre-tax	$	1,922		$	1,429			$	426		$	331
	compensation expense
	Tax benefit	$	739		$	550			$	164		$	127

Regulatory_Assets_and_Liabilit1

Regulatory Assets and Liabilities (Tables) (Cleco Power [Member])	3 Months Ended
	Mar. 31, 2014
Cleco Power [Member]	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'
Regulatory Assets and Liabilities	'
	The following table summarizes Cleco Power’s regulatory assets and liabilities at March 31, 2014 and December 31, 2013:
	(THOUSANDS)	AT MAR. 31, 2014		AT DEC. 31, 2013
	Regulatory assets – deferred taxes, net	$	230,489	$	229,173
	Mining costs	$	13,382	$	14,019
	Interest costs	5,853		5,943
	Asset removal costs	954		936
	Postretirement plan costs	91,638		93,333
	Tree trimming costs	5,560		4,840
	Training costs	7,136		7,175
	Surcredits, net	17,033		16,738
	Amended Lignite mining agreement contingency	3,781		3,781
	Power purchase agreement capacity costs	6,143		9,749
	AMI deferred revenue requirement	5,400		4,682
	Production Operations & Maintenance expenses	8,459		8,459
	AFUDC equity gross-up	73,257		73,306
	Rate case costs	—		45
	Acadia Unit 1 acquisition costs	2,734		2,760
	Financing costs	9,679		9,772
	Biomass costs	106		114
	Total regulatory assets – other	$	251,115	$	255,652
	Fuel and purchased power	1,582		(3,869		)
	Total regulatory assets, net	$	483,186	$	480,956

Fair_Value_Accounting_Tables

Fair Value Accounting (Tables)	3 Months Ended
	Mar. 31, 2014
Fair Value [Line Items]	'
Fair Value By Balance Sheet Grouping	'
	Note 4 — Fair Value Accounting
	The amounts reflected in Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2014 and December 31, 2013, for cash equivalents, restricted cash equivalents, accounts receivable, other accounts receivable, accounts payable, and short-term debt 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 Condensed Consolidated Balance Sheets.
	Cleco
		AT MAR. 31, 2014								AT DEC. 31, 2013
	(THOUSANDS)	CARRYING				ESTIMATED				CARRYING			ESTIMATED
		VALUE				FAIR VALUE				VALUE			FAIR VALUE
	Financial instruments not marked-to-market:
	Cash equivalents	$	12,176			$	12,176			$	22,204		$	22,204
	Restricted cash equivalents	$	18,362			$	18,362			$	14,019		$	14,019
	Long-term debt, excluding debt issuance costs	$	1,313,649			$	1,473,263			$	1,331,230		$	1,420,048
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 and within the scope of the authoritative guidance for fair value measurements and disclosures.
	Cleco
		CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
	(THOUSANDS)	AT MAR. 31, 2014				QUOTED PRICES IN				SIGNIFICANT			SIGNIFICANT			AT DEC. 31, 2013		QUOTED PRICES IN		SIGNIFICANT		SIGNIFICANT
						ACTIVE MARKETS				OTHER			UNOBSERVABLE					ACTIVE MARKETS		OTHER		UNOBSERVABLE
						FOR IDENTICAL				OBSERVABLE			INPUTS					FOR IDENTICAL		OBSERVABLE		INPUTS
						ASSETS				INPUTS			(LEVEL 3)					ASSETS		INPUTS		(LEVEL 3)
						(LEVEL 1)				(LEVEL 2)								(LEVEL 1)		(LEVEL 2)
	Asset Description
	Institutional money market funds	$	30,538			$	—			$	30,538		$	—		$	36,100	$	—	$	36,100	$	—
	Commercial paper	—				—				—			—			1,483		—		1,483		—
	Municipal bonds	—				—				—			—			9,831		—		9,831		—
	Corporate bonds	—				—				—			—			515		—		515		—
	Federal agency mortgage-backed securities	—				—				—			—			1,000		—		1,000		—
	FTRs	3,972				—				—			3,972			9,020		—		—		9,020
	Total assets	$	34,510			$	—			$	30,538		$	3,972		$	57,949	$	—	$	48,929	$	9,020
	Liability Description
	Long-term debt	1,473,263				—				1,473,263			—			1,420,048		—		1,420,048		—
	FTRs	64				—				—			64			382		—		—		382
	Total liabilities	$	1,473,327			$	—			$	1,473,263		$	64		$	1,420,430	$	—	$	1,420,048	$	382
Effect of Derivatives On Consolidated Statements of Income	'
	The following table presents the effect of derivatives designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2014 and 2013.
		FOR THE THREE MONTHS ENDED MAR. 31,
		2014								2013
	(THOUSANDS)	AMOUNT				AMOUNT OF LOSS				AMOUNT			AMOUNT OF LOSS
		OF GAIN				RECLASSIFIED FROM				OF GAIN			RECLASSIFIED FROM
		RECOGNIZED				ACCUMULATED OCI				RECOGNIZED			ACCUMULATED OCI
		IN OCI				INTO INCOME				IN OCI			INTO INCOME
						(EFFECTIVE PORTION)							(EFFECTIVE PORTION)
	Interest rate	$	—			$	(86	)*		$	1,762		$	(20	)*
	derivatives (1)
	* The loss reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.
	(1) During the three months ended March 31, 2013, Cleco recorded ineffectiveness and losses related to the interest rate derivatives as a regulatory asset of $0.4 million.
Fair Value, Net Derivative Asset (Liability) Measured on Recurring Basis, Unobservable Input Reconciliation	'
	The following table summarizes the changes in the fair value of FTR assets and liabilities classified as Level 3 in the fair value hierarchy as of March 31, 2014:
	(THOUSANDS)
	Beginning balance at January 1, 2014	$	8,638
	Realized losses	(747		)	*
	Unrealized losses	(1,060		)	*
	Purchases	(85		)
	Sales	(321		)
	Settlements	(2,517		)
	Ending balance at March 31, 2014	$	3,908
	* Unrealized gains and losses are reported in Accumulated deferred fuel on the balance sheet. As gains and losses are realized in future periods, they will be recorded as Electric operations or Power purchased for utility customers on the income statement.
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques	'
	The following table quantifies the significant unobservable inputs used in developing the fair value of Level 3 positions at March 31, 2014 and December 31, 2013:
		FAIR VALUE								VALUATION TECHNIQUE		SIGNIFICANT	FORWARD PRICE RANGE
												UNOBSERVABLE INPUTS
	(THOUSANDS, EXCEPT FORWARD PRICE RANGE)	Assets				Liabilities							Low			High
	FTRs at Mar. 31, 2014	$	3,972			$	64			Discounted cash flow		Estimated auction price	$	(5.24	)	$	6.95
	FTRs at Dec. 31, 2013	$	9,020			$	382			Discounted cash flow		Estimated auction price	$	(4.88	)	$	33.75
Cleco Power [Member]	'
Fair Value [Line Items]	'
Fair Value By Balance Sheet Grouping	'
	Cleco Power
		AT MAR. 31, 2014								AT DEC. 31, 2013
	(THOUSANDS)	CARRYING				ESTIMATED				CARRYING			ESTIMATED
		VALUE				FAIR VALUE				VALUE			FAIR VALUE
	Financial instruments not marked-to-market:
	Cash equivalents	$	5,900			$	5,900			$	14,900		$	14,900
	Restricted cash equivalents	$	18,341			$	18,341			$	13,998		$	13,998
	Long-term debt, excluding debt issuance costs	$	1,298,649			$	1,458,263			$	1,326,230		$	1,415,048
Schedule of Available-for-sale Securities Reconciliation	'
	The following table provides a reconciliation of Cleco Power’s available-for-sale debt securities from amortized cost to fair value at December 31, 2013:
		AT DEC. 31, 2013
	(THOUSANDS)	AMORTIZED				TOTAL				TOTAL			FAIR VALUE
		COST				UNREALIZED GAINS (1)				UNREALIZED
										LOSSES (1)
	Municipal bonds	$	9,838			$	8			$	15		$	9,831
	Corporate bonds	513				2				—			515
	Federal agency mortgage-backed securities	1,000				—				—			1,000
	Commercial paper	1,483				—				—			1,483
	Total available-for-sale debt securities	$	12,834			$	10			$	15		$	12,829
	(1)  Unrealized gains and losses are recorded to the restricted storm reserve.
Fair Value of Financial Assets and Liabilities Measured On A Recurring Basis	'
	Cleco Power
		CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
	(THOUSANDS)	AT MAR. 31, 2014				QUOTED PRICES IN				SIGNIFICANT			SIGNIFICANT			AT DEC. 31, 2013		QUOTED PRICES IN		SIGNIFICANT		SIGNIFICANT
						ACTIVE MARKETS				OTHER			UNOBSERVABLE					ACTIVE MARKETS		OTHER		UNOBSERVABLE
						FOR IDENTICAL				OBSERVABLE			INPUTS					FOR IDENTICAL		OBSERVABLE		INPUTS
						ASSETS				INPUTS			(LEVEL 3)					ASSETS		INPUTS		(LEVEL 3)
						(LEVEL 1)				(LEVEL 2)								(LEVEL 1)		(LEVEL 2)
	Asset Description
	Institutional money market funds	$	24,241			$	—			$	24,241		$	—		$	28,775	$	—	$	28,775	$	—
	Commercial paper	—				—				—			—			1,483		—		1,483		—
	Municipal bonds	—				—				—			—			9,831		—		9,831		—
	Corporate bonds	—				—				—			—			515		—		515		—
	Federal agency mortgage-backed securities	—				$	—			—			—			1,000		—		1,000		—
	FTRs	3,972				$	—			—			3,972			9,020		—		—		9,020
	Total assets	$	28,213			$	—			$	24,241		$	3,972		$	50,624	$	—	$	41,604	$	9,020
	Liability Description
	Long-term debt	1,458,263				—				1,458,263			—			1,415,048		—		1,415,048		—
	FTRs	64				—				—			64			382		—		—		382
	Total liabilities	$	1,458,327			$	—			$	1,458,263		$	64		$	1,415,430	$	—	$	1,415,048	$	382
Not Designated as Hedging Instrument [Member]	'
Fair Value [Line Items]	'
Schedule of Derivative Instruments in Statement of Financial Position, Fair Value	'
	The following table presents the fair values of derivative instruments and their respective line items as recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2014 and December 31, 2013:
		DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
	(THOUSANDS)	BALANCE SHEET LINE ITEM		AT MAR. 31, 2014				AT DEC. 31, 2013
	Commodity contracts
	FTRs:
	Current	Energy risk management assets		$	3,972			$	9,020
	Current	Energy risk management liabilities		64				382
	Total			$	3,908			$	8,638
Effect of Derivatives On Consolidated Statements of Income	'
	The following table presents the effect of derivatives not designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2014:
		FOR THE THREE MONTHS ENDED MAR. 31,
				2014
	(THOUSANDS)	DERIVATIVES LINE ITEM		AMOUNT OF GAIN/(LOSS)
				RECOGNIZED IN
				INCOME ON
				DERIVATIVES
	Commodity contracts
	FTRs	Electric operations		$	3,965
	FTRs	Power purchased for utility customers		(1,115		)
	Total			$	2,850

Pension_Plan_and_Employee_Bene1

Pension Plan and Employee Benefits (Tables)	3 Months Ended
	Mar. 31, 2014
401(k) Plan [Abstract]	'
401(k) Plan expense	'
	Cleco’s 401(k) Plan expense for the three months ended March 31, 2014 and 2013 is as follows:
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013
	401(k) Plan expense	$	1,369		$	1,279
Pension Benefits [Member]	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Net periodic benefit costs	'
	The components of net periodic pension and other benefit cost for the three months ended March 31, 2014 and 2013, are as follows:
		PENSION BENEFITS						OTHER BENEFITS
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013			2014		2013
	Components of periodic benefit cost:
	Service cost	$	2,005		$	2,484		$	405	$	314
	Interest cost	4,930			4,437			463		481
	Expected return on plan assets	(6,083		)	(5,764		)	—		—
	Amortizations:
	Transition obligation	—			—			5		4
	Prior period service cost (credit)	(18		)	(18		)	30		—
	Net loss	1,713			3,373			177		318
	Net periodic benefit cost	$	2,547		$	4,512		$	1,080	$	1,117
SERP Benefits [Member]	'
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]	'
Net periodic benefit costs	'
	The components of net periodic SERP benefit cost for the three months ended March 31, 2014 and 2013, are as follows:
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013
	Components of periodic benefit cost:
	Service cost	$	468		$	506
	Interest cost	725			678
	Amortizations:
	Prior period service cost	12			14
	Net loss	385			536
	Net periodic benefit cost	$	1,590		$	1,734

Income_Taxes_Tables

Income Taxes (Tables)	3 Months Ended
	Mar. 31, 2014
Income Tax Disclosure [Abstract]	'
Effective income tax rates	'
	The following table summarizes the effective income tax rates for Cleco and Cleco Power for the three month periods ended March 31, 2014 and 2013.
		FOR THE THREE MONTHS ENDED MAR. 31,
		2014		2013
	Cleco	34.5	%	32.5	%
	Cleco Power	35.1	%	33.9	%
Liability and expense related to unrecognized tax benefits	'
	The total amounts of interest payable and interest expense related to uncertain tax positions, as reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets and Statements of Income, are shown in the following tables.
	(THOUSANDS)	AT MAR. 31, 2014			AT DEC. 31, 2013
	Interest payable
	Cleco	$	96		$	88
	Cleco Power	$	12		$	11
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014			2013
	Interest charges
	Cleco	$	30		$	(69	)
	Cleco Power	$	1		$	121

Disclosures_about_Segments_Tab

Disclosures about Segments (Tables)	3 Months Ended
	Mar. 31, 2014
Segment Reporting [Abstract]	'
Segment Information	'
	SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MAR. 31,
	2014 (THOUSANDS)	CLECO POWER			MIDSTREAM			OTHER			ELIMINATIONS			CONSOLIDATED
	Revenue
	Electric operations	$	269,759		$	—		$	—		$	—		$	269,759
	Tolling operations	—			5,467			—			(5,467		)	—
	Other operations	14,272			—			541			1			14,814
	Electric customer credits	(186		)	—			—			—			(186		)
	Affiliate revenue	335			—			13,192			(13,527		)	—
	Operating revenue, net	$	284,180		$	5,467		$	13,733		$	(18,993	)	$	284,387
	Depreciation	$	40,203		$	1,269		$	269		$	—		$	41,741
	Interest charges	$	19,758		$	13		$	362		$	135		$	20,268
	Interest income	$	602		$	—		$	(133	)	$	133		$	602
	Federal and state income tax expense (benefit)	$	14,210		$	(81	)	$	(451	)	$	—		$	13,678
	Net income (loss)	$	26,307		$	(130	)	$	(252	)	$	(1	)	$	25,924
	Additions to (reductions in) long-lived assets	$	234,153		$	(176,293	)	$	196		$	—		$	58,056
	Equity investment in investees	$	14,532		$	—		$	8		$	—		$	14,540
	Total segment assets	$	4,091,584		$	51,180		$	66,632		$	(26,399	)	$	4,182,997
	2013 (THOUSANDS)	CLECO POWER			MIDSTREAM			OTHER			ELIMINATIONS			CONSOLIDATED
	Revenue
	Electric operations	$	229,425		$	—		$	—		$	—		$	229,425
	Tolling operations	—			4,837			—			(4,837		)	—
	Other operations	11,038			1			504			—			11,543
	Electric customer credits	(21		)	—			—			—			(21		)
	Affiliate revenue	336			—			11,925			(12,261		)	$	—
	Operating revenue, net	$	240,778		$	4,838		$	12,429		$	(17,098	)	$	240,947
	Depreciation	$	32,330		$	1,500		$	203		$	(1	)	$	34,032
	Interest charges	$	21,349		$	(239	)	$	163		$	183		$	21,456
	Interest income	$	198		$	—		$	(180	)	$	183		$	201
	Federal and state income tax expense (benefit)	$	14,238		$	(840	)	$	(317	)	$	—		$	13,081
	Net income (loss)	$	27,793		$	(1,334	)	$	674		$	—		$	27,133
	Additions to long-lived assets	$	41,558		$	1,829		$	561		$	—		$	43,948
	Equity investment in investees (1)	$	14,532		$	—		$	8		$	—		$	14,540
	Total segment assets  (1)	$	3,943,712		$	225,832		$	88,234		$	(42,516	)	$	4,215,262
	(1) Balances as of December 31, 2013

Variable_Interest_Entities_Tab

Variable Interest Entities (Tables)	3 Months Ended
	Mar. 31, 2014
Variable Interest Entities [Abstract]	'
Components of Equity Investments	'
	The following table presents the components of Cleco Power’s equity investment in Oxbow.
	INCEPTION TO DATE (THOUSANDS)	AT MAR. 31, 2014		AT DEC. 31, 2013
	Purchase price	$	12,873	$	12,873
	Cash contributions	1,659		1,659
	Total equity investment in investee	$	14,532	$	14,532
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’s maximum exposure to loss related to its investment in Oxbow.
	(THOUSANDS)	AT MAR. 31, 2014		AT DEC. 31, 2013
	Oxbow’s net assets/liabilities	$	29,065	$	29,065
	Cleco Power’s 50% equity	$	14,532	$	14,532
	Cleco’s maximum exposure to loss	$	14,532	$	14,532
Equity Method Investments - Summarized Financial Information	'
	The following tables contain summarized financial information for Oxbow.
	(THOUSANDS)	AT MAR. 31, 2014		AT DEC. 31, 2013
	Current assets	$	2,303	$	2,289
	Property, plant, and equipment, net	22,587		22,611
	Other assets	4,248		4,256
	Total assets	$	29,138	$	29,156
	Current liabilities	$	61	$	91
	Other liabilities	12		—
	Partners’ capital	29,065		29,065
	Total liabilities and partners’ capital	$	29,138	$	29,156
		FOR THE THREE MONTHS ENDED MAR. 31,
	(THOUSANDS)	2014		2013
	Operating revenue	$	585	$	429
	Operating expenses	585		429
	Income before taxes	$	—	$	—

Litigation_Other_Commitments_a1

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees (Tables)	3 Months Ended
	Mar. 31, 2014
Other Commitments [Line Items]	'
Other Commitments	'
	The following table summarizes the expected amount of commitment termination per period of off-balance sheet commitments and on-balance sheet guarantees discussed above.
								AT MAR. 31, 2014
				AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
	(THOUSANDS)	NET		LESS THAN		1-3 YEARS		3-5 YEARS		MORE
		AMOUNT		ONE YEAR						THAN
		COMMITTED								5 YEARS
	Off-balance sheet commitments	$	5,225	$	3,725	$	—	$	1,000	$	500
	On-balance sheet guarantees	4,906		900		—		—		4,006
	Total	$	10,131	$	4,625	$	—	$	1,000	$	4,506
Off-Balance Sheet Commitments	'
	Cleco’s off-balance sheet commitments as of March 31, 2014, are summarized in the following table and a discussion of the off-balance sheet commitments follows the table. The discussion should be read in conjunction with the table to understand the impact of the off-balance sheet commitments on Cleco’s financial condition.
		AT MAR. 31, 2014
	(THOUSANDS)	FACE AMOUNT
	Cleco Corporation
	Guarantee issued to Entergy Mississippi on behalf of Attala	$	500
	Cleco Power
	Obligations under standby letter of credit issued to the Louisiana Department of Labor	3,725
	Obligations under standby letter of credit issued to MISO	1,000
	Total	$	5,225
	There were no reductions against the face amount for any of these commitments.
Equity Investments with an Imputed Interest Rate	'
	The following table contains the disclosures required by the authoritative guidelines for equity investments with an imputed interest rate.
	(THOUSANDS)
	Equity contributions, imputed interest rate 6%
	Principal payment schedule above:	$	54,058
	Less:  unamortized discount	3,011
	Total	$	51,047
New Markets Tax Credit [Member]	'
Other Commitments [Line Items]	'
Other Commitments	'
	The following table reflects remaining future equity contributions.
	(THOUSANDS)	CONTRIBUTION
	Nine months ending Dec. 31, 2014	$	36,252
	Years ending Dec. 31,
	2015	11,195
	2016	3,698
	2017	2,913
	Total	$	54,058

Affiliate_Transactions_Affilia

Affiliate Transactions Affiliate Transactions (Tables) (Cleco Power [Member])	3 Months Ended
	Mar. 31, 2014
Cleco Power [Member]	'
Related Party Transaction [Line Items]	'
Schedule of Related Party Transactions [Table Text Block]	'
	Cleco Power has affiliate balances that are payable to or due from its affiliates. The following table is a summary of those balances.
		AT MAR. 31, 2014				AT DEC. 31, 2013
	(THOUSANDS)	ACCOUNTS		ACCOUNTS		ACCOUNTS		ACCOUNTS
		RECEIVABLE		PAYABLE		RECEIVABLE		PAYABLE
	Cleco Corporation	$	1,773	$	712	$	379	$	389
	Support Group	853		6,203		634		5,972
	Midstream	265		11		27		1
	Evangeline	38		867		4		2,024
	Diversified Lands	1		—		1		—
	Other (1)	2		—		—		—
	Total	$	2,932	$	7,793	$	1,045	$	8,386
	(1) Represents Perryville and Attala

Accumulated_Other_Comprehensiv1

Accumulated Other Comprehensive Loss (Tables)	3 Months Ended
	Mar. 31, 2014
Accumulated Other Comprehensive Loss [Line Items]	'
Schedule of Accumulated Other Comprehensive Income (Loss)	'
	The components of accumulated other comprehensive loss are summarized in the following tables for Cleco and Cleco Power. All amounts are reported net of income taxes and amounts in parentheses indicate debits.
	Cleco
											FOR THE THREE MONTHS ENDED MAR. 31,
								2014									2013
	(THOUSANDS)	POSTRETIREMENT			NET LOSS			TOTAL			POSTRETIREMENT			NET LOSS			TOTAL
		BENEFIT NET LOSS			ON CASH FLOW			ACCUMULATED			BENEFIT NET LOSS			ON CASH FLOW			ACCUMULATED OTHER
					HEDGES			OTHER						HEDGES			COMPREHENSIVE
								COMPREHENSIVE									LOSS
								LOSS
	Balances at beginning of period	$	(19,725	)	$	(6,151	)	$	(25,876	)	$	(24,741	)	$	(7,629	)	$	(32,370	)
	Other comprehensive income before reclassifications:
	Net derivative gain	—			—			—			—			1,355			1,355
	Amounts reclassified from accumulated
	other comprehensive income:
	Amortization of postretirement benefit net loss	844			—			844			536			—			536
	Reclassification of net loss to interest charges	—			53			53			—			12			12
	Reclassification of ineffectiveness to regulatory asset	—			—			—			—			(30		)	(30		)
	Net current-period other comprehensive income	844			53			897			536			1,337			1,873
	Balances, Mar. 31,	$	(18,881	)	$	(6,098	)	$	(24,979	)	$	(24,205	)	$	(6,292	)	$	(30,497	)
Cleco Power [Member]	'
Accumulated Other Comprehensive Loss [Line Items]	'
Schedule of Accumulated Other Comprehensive Income (Loss)	'
	Cleco Power
											FOR THE THREE MONTHS ENDED MAR. 31,
								2014									2013
	(THOUSANDS)	POSTRETIREMENT			NET LOSS			TOTAL			POSTRETIREMENT			NET LOSS			TOTAL
		BENEFIT NET LOSS			ON CASH FLOW			ACCUMULATED			BENEFIT NET LOSS			ON CASH FLOW			ACCUMULATED OTHER
					HEDGES			OTHER						HEDGES			COMPREHENSIVE
								COMPREHENSIVE									LOSS
								LOSS
	Balances at beginning of period	$	(9,026	)	$	(6,151	)	$	(15,177	)	$	(12,792	)	$	(7,629	)	$	(20,421	)
	Other comprehensive income before reclassifications:
	Net derivative gain	—			—			—			—			1,355			1,355
	Amounts reclassified from accumulated
	other comprehensive income:
	Amortization of postretirement benefit net loss	525			—			525			251			—			251
	Reclassification of net loss to interest charges	—			53			53			—			12			12
	Reclassification of ineffectiveness to regulatory asset	—			—			—			—			(30		)	(30		)
	Net current-period other comprehensive income	525			53			578			251			1,337			1,588
	Balances, Mar. 31,	$	(8,501	)	$	(6,098	)	$	(14,599	)	$	(12,541	)	$	(6,292	)	$	(18,833	)

Summary_of_Significant_Account3

Summary of Significant Accounting Policies, Property, Plant, and Equipment (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Public Utility, Property, Plant, and Equipment [Line Items]	'	'
Regulated utility plants	$4,311,221	$4,052,774
Other	15,096	273,748
Total property, plant, and equipment	4,326,317	4,326,522
Accumulated depreciation	-1,371,281	-1,351,223
Net property, plant, and equipment	2,955,036	2,975,299
Cleco Power [Member]	'	'
Public Utility, Property, Plant, and Equipment [Line Items]	'	'
Total property, plant, and equipment	4,311,221	4,052,774
Accumulated depreciation	-1,361,984	-1,260,843
Net property, plant, and equipment	2,949,237	2,791,931
Transfer of Coughlin from affiliate [Member] | Evangeline [Member] | Cleco Power [Member]	'	'
Public Utility, Property, Plant, and Equipment [Line Items]	'	'
Accumulated depreciation	-82,600	'
Net property, plant, and equipment	$176,000	'

Summary_of_Significant_Account4

Summary of Significant Accounting Policies, Restricted Cash and Cash Equivalents (Details) (USD $)

3 Months Ended

1 Months Ended

3 Months Ended

3 Months Ended

Mar. 31, 2014

Mar. 31, 2013

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Diversified Lands Mitigation Escrow Agreement [Member]

Diversified Lands Mitigation Escrow Agreement [Member]

Katrina/Rita Bond Payments [Member]

Katrina/Rita Bond Payments [Member]

Katrina/Rita Bond Payments [Member]

Future Storm Restoration Costs [Member]

Future Storm Restoration Costs [Member]

Building Renovations Escrow [Member]

Building Renovations Escrow [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Future Storm Restoration Costs [Member]

Restricted Cash and Cash Equivalents Items [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted cash and cash equivalents

$18,387,000

'

$14,019,000

$21,000

$21,000

$3,893,000

$3,893,000

$8,986,000

$14,025,000

$4,726,000

$448,000

$286,000

'

'

'

Restricted Cash and Cash Equivalents, Cleco Katrina/Rita Storm Recover Bond Variance [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Restricted cash collected by Cleco Katrina/Rita, net of administration fees

'

'

'

'

'

'

5,500,000

'

'

'

'

'

'

'

'

Restricted cash used by Cleco Katrina/Rita for bond principal payments

'

'

'

'

'

7,600,000

'

'

'

'

'

'

'

'

'

Restricted cash used by Cleco Katrina/Rita for bond interest payments

'

'

'

'

'

3,000,000

'

'

'

'

'

'

'

'

'

Increase in Restricted Cash

4,367,000

-5,154,000

'

'

'

'

'

'

'

'

'

'

4,367,000

-5,154,000

9,300,000

Transfer of restricted investments to restricted cash

'

'

'

'

'

'

'

'

'

'

'

'

'

'

13,200,000

Transfer of restricted cash to cover storm expenses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$4,000,000

Summary_of_Significant_Account5

Summary of Significant Accounting Policies Summary of Significant Accounting Policies, Risk Management (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Energy risk management liabilities [Member]	'	'
Derivative Instruments and Hedging Activities Disclosures [Line Items]	'	'
FTRs in Energy risk management liability	$64	$382
Energy risk management asset [Member]	'	'
Derivative Instruments and Hedging Activities Disclosures [Line Items]	'	'
FTRs in Energy risk management asset	$3,972	$9,020
Cleco Power [Member] | Natural gas derivative [Member]	'	'
Derivative Instruments and Hedging Activities Disclosures [Line Items]	'	'
Number of open derivative positions	0	0

Summary_of_Significant_Account6

Summary of Significant Accounting Policies, Earnings Per Average Common Share (Details) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Income	'	'
Basic net income applicable to common stock	$25,924	$27,133
Diluted net income applicable to common stock	$25,924	$27,133
Shares	'	'
Average number of basic common shares outstanding (in shares)	60,472,969	60,399,697
Effect of dilutive securities	'	'
Add: restricted stock (LTICP) (in shares)	240,618	267,704
Average number of diluted common shares outstanding (in shares)	60,713,587	60,667,401
Per Share Amount	'	'
Net income applicable to common stock (in dollars per share)	$0.43	$0.45
Diluted net income per average common share (in dollars per share)	$0.43	$0.45
Stock Options [Member]	'	'
Per Share Amount	'	'
Amount of stock options excluded from computation of diluted earnings per share (in shares)	0	0

Summary_of_Significant_Account7

Summary of Significant Accounting Policies, Stock-Based Compensation (Details) (USD $)	3 Months Ended
In Thousands, except Share data, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Stock-Based Compensation [Line Items]	'	'
Share-based compensation expense	$1,922	$1,429
Tax benefit	739	550
Equity Classification [Member]	'	'
Stock-Based Compensation [Line Items]	'	'
Share-based compensation expense	1,922	1,428
Non-vested Stock [Member]	'	'
Stock-Based Compensation [Line Items]	'	'
Share-based compensation expense	1,922	1,428
Common Stock Equivalent Units [Member]	'	'
Stock-Based Compensation [Line Items]	'	'
Share-based compensation expense	0	1
Cleco Power [Member]	'	'
Stock-Based Compensation [Line Items]	'	'
Share-based compensation expense	426	331
Tax benefit	164	127
Cleco Power [Member] | Equity Classification [Member]	'	'
Stock-Based Compensation [Line Items]	'	'
Share-based compensation expense	426	331
Cleco Power [Member] | Non-vested Stock [Member]	'	'
Stock-Based Compensation [Line Items]	'	'
Share-based compensation expense	426	331
Cleco Power [Member] | Common Stock Equivalent Units [Member]	'	'
Stock-Based Compensation [Line Items]	'	'
Share-based compensation expense	$0	$0
LTIP [Member] | Non-vested Stock [Member]	'	'
Stock-Based Compensation [Line Items]	'	'
Non-vested stock granted during the period (in shares)	120,935	'

Summary_of_Significant_Account8

Summary of Significant Accounting Policies Summary of Significant Accounting Policies, Common Stock Repurchase Program (Details)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Accounting Policies [Abstract]	'	'
Repurchase of common stock (in shares)	250,000	0

Regulatory_Assets_and_Liabilit2

Regulatory Assets and Liabilities, Summary of Regulatory Assets and Liabilities (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets and liabilities - deferred taxes, net	$230,489	$229,173
Cleco Power [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets and liabilities - deferred taxes, net	230,489	229,173
Total regulatory assets, net	483,186	480,956
Cleco Power [Member] | Fuel and purchased power [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory liabilities	'	-3,869
Cleco Power [Member] | Deferred taxes, net [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets and liabilities - deferred taxes, net	230,489	229,173
Cleco Power [Member] | Total regulatory assets - other [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	251,115	255,652
Cleco Power [Member] | Mining costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	13,382	14,019
Cleco Power [Member] | Interest costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	5,853	5,943
Cleco Power [Member] | Asset removal costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	954	936
Cleco Power [Member] | Postretirement plan costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	91,638	93,333
Cleco Power [Member] | Tree trimming costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	5,560	4,840
Cleco Power [Member] | Training costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	7,136	7,175
Cleco Power [Member] | Surcredits, net [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	17,033	16,738
Cleco Power [Member] | Amended lignite mining agreement contingency [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	3,781	3,781
Cleco Power [Member] | Power purchase agreement capacity costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	6,143	9,749
Cleco Power [Member] | AMI deferred revenue requirement [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	5,400	4,682
Cleco Power [Member] | Production O&M Expenses [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	8,459	8,459
Cleco Power [Member] | AFUDC equity gross-up [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	73,257	73,306
Cleco Power [Member] | Rate case costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	0	45
Cleco Power [Member] | Acadia Unit 1 acquisition costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	2,734	2,760
Cleco Power [Member] | Financing costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	9,679	9,772
Cleco Power [Member] | Biomass costs [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	106	114
Cleco Power [Member] | Fuel and purchased power [Member]	'	'
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'
Regulatory assets	$1,582	'

Regulatory_Assets_and_Liabilit3

Regulatory Assets and Liabilities, Additional Disclosures (Details) (Cleco Power [Member], USD $)	36 Months Ended		3 Months Ended
In Millions, unless otherwise specified	Apr. 30, 2015	Mar. 31, 2012	Mar. 31, 2014	Mar. 31, 2014
	Evangeline [Member]	Evangeline [Member]	Fuel and purchased power [Member]	Fuel and purchased power [Member]
	Evangeline Power Purchase Agreement [Member]	Evangeline Power Purchase Agreement [Member]		FTRs [Member]
	MW
Schedule of Regulatory Assets and Liabilities, Net [Line Items]	'	'	'	'
Long-term power purchase agreement, term (in years)	'	'3 years	'	'
Capacity and energy provided by a power purchase agreement (in MW)	730	'	'	'
Percentage of total fuel cost regulated by LPSC (in hundredths)	'	'	88.00%	'
Increase (decrease) in other regulatory assets	'	'	$5.50	'
Decrease in net mark-to-market gains as a result of lower valuation of open FTRs	'	'	'	4.7
Increase in fuel and purchased power costs	'	'	$0.80	'

Fair_Value_Accounting_Carrying

Fair Value Accounting, Carrying Value and Estimated Fair Value (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Carrying Value [Member]	'	'
Financial instruments not marked-to-market [Abstract]	'	'
Cash equivalents	$12,176	$22,204
Restricted cash equivalents	18,362	14,019
Long-term debt, excluding debt issuance costs	1,313,649	1,331,230
Estimated Fair Value [Member]	'	'
Financial instruments not marked-to-market [Abstract]	'	'
Cash equivalents	12,176	22,204
Restricted cash equivalents	18,362	14,019
Long-term debt, excluding debt issuance costs	1,473,263	1,420,048
Cleco Power [Member] | Carrying Value [Member]	'	'
Financial instruments not marked-to-market [Abstract]	'	'
Cash equivalents	5,900	14,900
Restricted cash equivalents	18,341	13,998
Long-term debt, excluding debt issuance costs	1,298,649	1,326,230
Cleco Power [Member] | Estimated Fair Value [Member]	'	'
Financial instruments not marked-to-market [Abstract]	'	'
Cash equivalents	5,900	14,900
Restricted cash equivalents	18,341	13,998
Long-term debt, excluding debt issuance costs	$1,458,263	$1,415,048

Fair_Value_Accounting_Fair_Val

Fair Value Accounting, Fair Value Measurements and Disclosures(Details) (USD $)

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

In Thousands, unless otherwise specified

Cash and Cash Equivalents [Member]

Restricted Cash and Cash Equivalents, Current [Member]

Restricted Cash and Cash Equivalents, Noncurrent [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

FTRs [Member]

FTRs [Member]

FTRs [Member]

FTRs [Member]

FTRs [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Cash and Cash Equivalents [Member]

Restricted Cash and Cash Equivalents, Current [Member]

Restricted Cash and Cash Equivalents, Noncurrent [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Measured On A Recurring Basis [Member]

Significant Unobservable Inputs (Level 3) [Member]

Low [Member]

Low [Member]

High [Member]

High [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Restricted Investment, Noncurrent [Member]

Restricted Investment, Noncurrent [Member]

Restricted Investment, Noncurrent [Member]

Restricted Investment, Noncurrent [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Estimated Fair Value [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Other Observable Inputs (Level 2) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Significant Unobservable Inputs (Level 3) [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Commercial Paper [Member]

Commercial Paper [Member]

Municipal Bonds [Member]

Municipal Bonds [Member]

Corporate Bonds [Member]

Corporate Bonds [Member]

Federal Agency Mortgage-Backed Securities [Member]

Federal Agency Mortgage-Backed Securities [Member]

Asset Description

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Institutional money market funds

$12,200

$3,900

$14,400

$30,538

$36,100

'

'

'

'

'

'

'

'

$0

$0

'

'

'

'

'

'

'

'

$30,538

$36,100

'

'

'

'

'

'

'

'

$0

$0

'

'

'

'

'

'

'

'

$5,900

$3,900

$14,400

'

'

'

'

'

'

'

'

$24,241

$28,775

'

'

'

'

'

'

'

'

$0

$0

'

'

'

'

'

'

'

'

$24,241

$28,775

'

'

'

'

'

'

'

'

$0

$0

'

'

'

'

'

'

'

'

'

'

'

'

'

Available-for-sale debt securities

'

'

'

'

'

0

1,483

0

9,831

0

515

0

1,000

'

'

0

0

0

0

0

0

0

0

'

'

0

1,483

0

9,831

0

515

0

1,000

'

'

0

0

0

0

0

0

0

0

'

'

'

1,483

1,500

9,831

9,800

515

500

1,000

1,000

'

'

0

1,483

0

9,831

0

515

0

1,000

'

'

0

0

0

0

0

0

0

0

'

'

0

1,483

0

9,831

0

515

0

1,000

'

'

0

0

0

0

0

0

0

0

'

'

'

'

'

FTR assets

'

'

'

3,972

9,020

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

3,972

9,020

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

3,972

9,020

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

3,972

9,020

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Assets

'

'

'

34,510

57,949

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

30,538

48,929

'

'

'

'

'

'

'

'

3,972

9,020

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

28,213

50,624

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

24,241

41,604

'

'

'

'

'

'

'

'

3,972

9,020

'

'

'

'

'

'

'

'

'

'

'

'

'

Liability Description

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Long-term debt

'

'

'

1,473,263

1,420,048

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

1,473,263

1,420,048

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,458,263

1,415,048

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

1,458,263

1,415,048

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

'

'

'

'

'

FTR liabilities

'

'

'

64

382

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

64

382

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

64

382

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

64

382

'

'

'

'

'

'

'

'

'

'

'

'

'

Total Liabilities

'

'

'

1,473,327

1,420,430

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

1,473,263

1,420,048

'

'

'

'

'

'

'

'

64

382

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

1,458,327

1,415,430

'

'

'

'

'

'

'

'

0

0

'

'

'

'

'

'

'

'

1,458,263

1,415,048

'

'

'

'

'

'

'

'

64

382

'

'

'

'

'

'

'

'

'

'

'

'

'

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

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Beginning fair value of FTR assets (liabilities), net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

8,638

'

'

'

'

Realized losses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-747

'

'

'

'

Unrealized losses

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-1,060

'

'

'

'

Purchases

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-85

'

'

'

'

Sales

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-321

'

'

'

'

Settlements

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-2,517

'

'

'

'

Ending fair value of FTR assets (liabilities), net

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

$3,908

'

'

'

'

FTRs Forward Price Range

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-5.24

-4.88

6.95

33.75

Fair_Value_Accounting_Restrict

Fair Value Accounting, Restricted Investments (Details) (Cleco Power [Member], USD $)	Jul. 02, 2012	Sep. 30, 2007	Mar. 31, 2014	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013	Dec. 31, 2013
			Restricted Storm Reserve [Member]	Available-For-Sale Debt Securities [Member]	Municipal Bonds [Member]	Corporate Bonds [Member]	Federal Agency Mortgage-Backed Securities [Member]	Commercial Paper [Member]
			Maximum [Member]
Schedule of Available-for-sale Securities [Line Items]	'	'	'	'	'	'	'	'
Available-for-sale Securities, Net Realized Gain (Loss)	'	'	$100,000	'	'	'	'	'
LPSC authorized storm reserve funding	'	50,000,000	'	'	'	'	'	'
Amount of restricted cash and cash equivalents transfered to an investment manager	13,000,000	'	'	'	'	'	'	'
Reconciliation of available-for-sale debt securities from amortized cost to fair value[Abstract]	'	'	'	'	'	'	'	'
Amortized Cost	'	'	'	12,834,000	9,838,000	513,000	1,000,000	1,483,000
Total Unrealized Gains	'	'	'	10,000	8,000	2,000	0	0
Total Unrealized Losses	'	'	'	15,000	15,000	0	0	0
Fair Value	'	'	'	$12,829,000	$9,831,000	$515,000	$1,000,000	$1,483,000

Fair_Value_Accounting_Derivati

Fair Value Accounting, Derivatives and Hedging (Details) (USD $)

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2014

Mar. 31, 2013

Mar. 31, 2014

Dec. 31, 2013

Nov. 14, 2011

30-May-13

7-May-13

Mar. 31, 2014

Mar. 31, 2014

Dec. 31, 2013

Energy risk management asset [Member]

Energy risk management asset [Member]

Energy risk management liabilities [Member]

Energy risk management liabilities [Member]

Electric operations [Member]

Power purchased for utility [Member]

Derivatives Not Designated As Hedging Instruments [Member]

Interest rate derivatives [Member]

Interest rate derivatives [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Derivatives Designated as Hedging Instruments [Member]

Derivatives Designated as Hedging Instruments [Member]

MW

MW

Interest rate swap [Member]

Interest rate swap [Member]

Interest rate swap [Member]

Interest rate derivatives [Member]

Natural gas derivative [Member]

Natural gas derivative [Member]

Derivatives Designated as Hedging Instruments [Member]

MMBTU

MMBTU

FTRs, at Fair Value, Net [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

FTRs in Energy risk management asset

'

'

$3,972,000

$9,020,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

FTRs in Energy risk management liability

'

'

'

'

64,000

382,000

'

'

'

'

'

'

'

'

'

'

'

'

'

Total FTRs Not Designated as Hedging Instruments, at Fair Value, Net

3,908,000

8,638,000

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

FTRs [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain (Loss) on FTRs Not Designated as Hedging Instruments

'

'

'

'

'

'

3,965,000

-1,115,000

'

'

'

'

'

'

'

'

'

'

'

Net gain (loss) on FTRs recognized in income

'

'

'

'

'

'

'

'

2,850,000

'

'

'

'

'

'

'

'

'

'

Number of open natural gas positions

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

0

0

Number of FTRs Held

'

'

'

'

'

'

'

'

'

'

'

3,800,000

6,800,000

'

'

'

'

'

'

Notional amount of derivative

'

'

'

'

'

'

'

'

'

'

'

'

'

50,000,000

'

'

'

'

'

Remaining maturity of derivative

'

'

'

'

'

'

'

'

'

'

'

'

'

'30 years

'

'

'

'

'

Interest rate on derivative

'

'

'

'

'

'

'

'

'

'

'

'

'

3.05%

'

'

'

'

'

Gain (Loss) on the settlement of forward starting interest rate derivative

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-3,300,000

'

'

'

Gain (Loss) deferred as a regulatory asset on settlement of forward starting interest rate derivative

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-2,900,000

'

'

'

Gain (loss) on forward starting interest rate swap remaining in accumulated other comprehensive income (loss)

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

-400,000

'

'

'

Amortization period of gain (loss) on settlement of the forward starting interest rate derivative

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'25 years

'

'

'

'

Schedule of Derivative Instruments [Abstract]

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

Gain (Loss) recognized in other comprehensive income (loss), effective portion

'

'

'

'

'

'

'

'

'

0

1,762,000

'

'

'

'

'

'

'

'

Gain (Loss) reclassified from accumulated OCI into income, effective portion

'

'

'

'

'

'

'

'

'

-86,000

-20,000

'

'

'

'

'

'

'

'

Net hedge ineffectiveness gain (loss)

'

'

'

'

'

'

'

'

'

'

-400,000

'

'

'

'

'

'

'

'

Interest rate cash flow hedge gain (loss) to be reclassified during the next 12 months

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

'

($300,000)

'

'

Debt_Shortterm_Debt_Details

Debt, Short-term Debt (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Short-term Debt [Line Items]	'	'
Short-term debt	$0	$0
Cleco Power [Member]	'	'
Short-term Debt [Line Items]	'	'
Short-term debt	$0	$0

Debt_Longterm_Debt_Details

Debt, Long-term Debt (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Dec. 31, 2013
Debt Instrument [Line Items]	'	'
Long-term debt outstanding, total	$1,310,000,000	'
Long-term debt due within one year	17,688,000	17,182,000
Capital lease payments due within one year	2,300,000	'
Increase (decrease) in debt instrument, net	-18,000,000	'
Line of Credit [Member]	'	'
Debt Instrument [Line Items]	'	'
Increase (decrease) in debt instrument, net	-10,000,000	'
Capital Lease Obligations [Member]	'	'
Debt Instrument [Line Items]	'	'
Increase (decrease) in debt instrument, net	-500,000	'
Debt Discount Amortization [Member]	'	'
Debt Instrument [Line Items]	'	'
Increase (decrease) in debt instrument, net	100,000	'
Cleco Katrina Rita Storm Recovery Bonds [Member] | Bonds [Member]	'	'
Debt Instrument [Line Items]	'	'
Principal payments for Cleco Katrina/Rita storm recovery bonds due within one year	15,400,000	'
Increase (decrease) in debt instrument, net	-7,600,000	'
Cleco Power [Member]	'	'
Debt Instrument [Line Items]	'	'
Long-term debt outstanding, total	1,300,000,000	'
Long-term debt due within one year	17,688,000	17,182,000
Capital lease payments due within one year	2,300,000	'
Increase (decrease) in debt instrument, net	-28,000,000	'
Cleco Power [Member] | Line of Credit [Member]	'	'
Debt Instrument [Line Items]	'	'
Increase (decrease) in debt instrument, net	-20,000,000	'
Cleco Power [Member] | Capital Lease Obligations [Member]	'	'
Debt Instrument [Line Items]	'	'
Increase (decrease) in debt instrument, net	-500,000	'
Cleco Power [Member] | Debt Discount Amortization [Member]	'	'
Debt Instrument [Line Items]	'	'
Increase (decrease) in debt instrument, net	100,000	'
Cleco Power [Member] | Cleco Katrina Rita Storm Recovery Bonds [Member] | Bonds [Member]	'	'
Debt Instrument [Line Items]	'	'
Principal payments for Cleco Katrina/Rita storm recovery bonds due within one year	15,400,000	'
Increase (decrease) in debt instrument, net	($7,600,000)	'

Debt_Credit_Facilities_Details

Debt, Credit Facilities (Details) (Line of Credit [Member], USD $)	Mar. 31, 2014	Mar. 31, 2014	Apr. 08, 2014
In Millions, unless otherwise specified	Cleco Power [Member]	Parent Company [Member]	Subsequent Event [Member]
			Cleco Power [Member]
Line of Credit Facility [Line Items]	'	'	'
Line of credit facility, amount outstanding	$0	$15	'
Line of credit facility, current borrowing capacity	300	250	'
Letters of credit outstanding, amount	$1	'	$2

Pension_Plan_and_Employee_Bene2

Pension Plan and Employee Benefits, Pension Plan and Other Benefits Plan (Details) (USD $)	3 Months Ended					1 Months Ended	3 Months Ended			3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013	Jan. 31, 2013	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013	Mar. 31, 2014	Mar. 31, 2013
	Pension Benefits [Member]	Pension Benefits [Member]	Other Benefits [Member]	Other Benefits [Member]	Other Benefits [Member]	Cleco Power [Member]	Cleco Power [Member]	Cleco Power [Member]	Cleco Power [Member]	Other Subsidiaries [Member]	Other Subsidiaries [Member]
						Pension Benefits [Member]	Other Benefits [Member]	Other Benefits [Member]	Other Benefits [Member]	Pension Benefits [Member]	Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]	'	'	'	'	'	'	'	'	'	'	'
Pension contributions designated for prior plan year	'	'	'	'	'	$34,000,000	'	'	'	'	'
Components of periodic benefit costs	'	'	'	'	'	'	'	'	'	'	'
Service cost	2,005,000	2,484,000	405,000	314,000	'	'	'	'	'	'	'
Interest cost	4,930,000	4,437,000	463,000	481,000	'	'	'	'	'	'	'
Expected return on plan assets	-6,083,000	-5,764,000	0	0	'	'	'	'	'	'	'
Transition obligation	0	0	5,000	4,000	'	'	'	'	'	'	'
Prior period service cost (credit)	-18,000	-18,000	30,000	0	'	'	'	'	'	'	'
Net loss	1,713,000	3,373,000	177,000	318,000	'	'	'	'	'	'	'
Net periodic benefit cost	2,547,000	4,512,000	1,080,000	1,117,000	'	'	900,000	1,000,000	'	500,000	600,000
Postemployment Benefits Liability, Current	'	'	$3,500,000	'	$3,500,000	'	$3,200,000	'	$3,200,000	'	'

Pension_Plan_and_Employee_Bene3

Pension Plan and Employee Benefits, SERP (Details) (SERP Benefits [Member], USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Defined Benefit Plan Disclosure [Line Items]	'	'	'
Defined Benefit Plan, Contributions by Employer	$0	$0	'
Components of periodic benefit costs	'	'	'
Service cost (credit)	468,000	506,000	'
Interest cost	725,000	678,000	'
Prior period service cost (credit)	12,000	14,000	'
Net loss	385,000	536,000	'
Net periodic benefit cost	1,590,000	1,734,000	'
Curent portion of SERP liability	2,700,000	'	2,700,000
Cleco Power [Member]	'	'	'
Components of periodic benefit costs	'	'	'
Net periodic benefit cost	300,000	400,000	'
Curent portion of SERP liability	$900,000	'	$700,000

Pension_Plan_and_Employee_Bene4

Pension Plan and Employee Benefits, 401 (K) Plans (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
401(k) Plan [Abstract]	'	'
401 (k) Plan expense	$1,369	$1,279
Other Subsidiaries [Member]	'	'
401(k) Plan [Abstract]	'	'
401 (k) Plan expense	$300	$400

Income_Taxes_Effective_Tax_Rat

Income Taxes, Effective Tax Rate Reconciliation (Details)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013
Effective Income Tax Rate [Line Items]	'	'
Effective income tax rates	34.50%	32.50%
Cleco Power [Member]	'	'
Effective Income Tax Rate [Line Items]	'	'
Effective income tax rates	35.10%	33.90%

Income_Taxes_Valuation_Allowan

Income Taxes, Valuation Allowance (Details) (New Markets Tax Credit Carryforward [Member], USD $)	3 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Dec. 31, 2013
New Markets Tax Credit Carryforward [Member]	'	'
Tax Credit Carryforward [Line Items]	'	'
Tax Credit Carryforward, Valuation Allowance	$0	'
Tax credit carryforwards	$96.50	$95.40
Expiration date	1-Jan-29	'

Income_Taxes_Income_Tax_Uncert

Income Taxes, Income Tax Uncertainties (Details) (USD $)	3 Months Ended
	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Uncertain Tax Positions [Abstract]	'	'	'
Interest payable associated with uncertain tax positions	$96,000	'	$88,000
Interest charges related to uncertain tax positions	30,000	-69,000	'
Cleco Power [Member]	'	'	'
Income Tax Contingency [Line Items]	'	'	'
Customer Surcredits - Interest Expenses	600,000	700,000	'
Uncertain Tax Positions [Abstract]	'	'	'
Interest payable associated with uncertain tax positions	12,000	'	11,000
Amounts expected to be recovered from customers under existing rate orders	8,700,000	'	8,400,000
Interest charges related to uncertain tax positions	$1,000	$121,000	'

Income_Taxes_Income_Tax_Examin

Income Taxes, Income Tax Examination (Details) (USD $)	Mar. 31, 2014	Jan. 31, 2013	Dec. 31, 2012	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014	Mar. 31, 2014
In Millions, unless otherwise specified	Internal Revenue Service (IRS) [Member]	Internal Revenue Service (IRS) [Member]	Internal Revenue Service (IRS) [Member]	Internal Revenue Service (IRS) [Member]	Internal Revenue Service (IRS) [Member]	State and Local Jurisdiction [Member]	State and Local Jurisdiction [Member]
				Minimum [Member]	Maximum [Member]	Minimum [Member]	Maximum [Member]
Income Tax Examination [Line Items]	'	'	'	'	'	'	'
Tax years that remain subject to examination	'	'	'	'2010	'2012	'2005	'2012
Summary of income tax examinations [Abstract]	'	'	'	'	'	'	'
Deposits with the IRS	'	'	$60.40	'	'	'	'
Refund adjustment from settlement with taxing authority	'	42.3	'	'	'	'	'
Income tax years currently under examination	'	'	'	'2010	'2012	'	'
Significant Change in Unrecognized Tax Benefits is Reasonably Possible, Estimated Range of Change, Upper Bound	($4.60)	'	'	'	'	'	'

Disclosures_about_Segments_Det

Disclosures about Segments (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
	entity
Segment Reporting Information [Line Items]	'	'	'
Number of transmission interconnection facility subsidiaries	2	'	'
Revenue	'	'	'
Electric operations	$269,759	$229,425	'
Tolling operations	0	0	'
Other operations	14,814	11,543	'
Electric customer credits	-186	-21	'
Affiliate revenue	0	0	'
Operating revenue, net	284,387	240,947	'
Depreciation	41,741	34,032	'
Interest charges	20,268	21,456	'
Interest income	602	201	'
Federal and state income tax expense (benefit)	13,678	13,081	'
Net Income (loss)	25,924	27,133	'
Additions to (reductions in) long-lived assets	58,056	43,948	'
Equity investment in investees	14,540	'	14,540
Total segment assets	4,182,997	'	4,215,262
Operating Segments [Member] | Midstream [Member]	'	'	'
Revenue	'	'	'
Electric operations	0	0	'
Tolling operations	5,467	4,837	'
Other operations	0	1	'
Electric customer credits	0	0	'
Affiliate revenue	0	0	'
Operating revenue, net	5,467	4,838	'
Depreciation	1,269	1,500	'
Interest charges	13	-239	'
Interest income	0	0	'
Federal and state income tax expense (benefit)	-81	-840	'
Net Income (loss)	-130	-1,334	'
Additions to (reductions in) long-lived assets	-176,293	1,829	'
Equity investment in investees	0	'	0
Total segment assets	51,180	'	225,832
Operating Segments [Member] | Corporate and Other [Member]	'	'	'
Revenue	'	'	'
Electric operations	0	0	'
Tolling operations	0	0	'
Other operations	541	504	'
Electric customer credits	0	0	'
Affiliate revenue	13,192	11,925	'
Operating revenue, net	13,733	12,429	'
Depreciation	269	203	'
Interest charges	362	163	'
Interest income	-133	-180	'
Federal and state income tax expense (benefit)	-451	-317	'
Net Income (loss)	-252	674	'
Additions to (reductions in) long-lived assets	196	561	'
Equity investment in investees	8	'	8
Total segment assets	66,632	'	88,234
Operating Segments [Member] | Cleco Power, LLC and Subsidiary, Segment [Member]	'	'	'
Revenue	'	'	'
Electric operations	269,759	229,425	'
Tolling operations	0	0	'
Other operations	14,272	11,038	'
Electric customer credits	-186	-21	'
Affiliate revenue	335	336	'
Operating revenue, net	284,180	240,778	'
Depreciation	40,203	32,330	'
Interest charges	19,758	21,349	'
Interest income	602	198	'
Federal and state income tax expense (benefit)	14,210	14,238	'
Net Income (loss)	26,307	27,793	'
Additions to (reductions in) long-lived assets	234,153	41,558	'
Equity investment in investees	14,532	'	14,532
Total segment assets	4,091,584	'	3,943,712
Intersegment Elimination [Member]	'	'	'
Revenue	'	'	'
Electric operations	0	0	'
Tolling operations	-5,467	-4,837	'
Other operations	1	0	'
Electric customer credits	0	0	'
Affiliate revenue	-13,527	-12,261	'
Operating revenue, net	-18,993	-17,098	'
Depreciation	0	-1	'
Interest charges	135	183	'
Interest income	133	183	'
Federal and state income tax expense (benefit)	0	0	'
Net Income (loss)	-1	0	'
Additions to (reductions in) long-lived assets	0	0	'
Equity investment in investees	0	'	0
Total segment assets	($26,399)	'	($42,516)

Electric_Customer_Credits_Deta

Electric Customer Credits (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013	Mar. 31, 2014	Dec. 31, 2013	Jun. 30, 2020	Jun. 30, 2013
			Cleco Power [Member]	Cleco Power [Member]	Cleco Power [Member]	Cleco Power [Member]
					Louisiana Public Service Commission [Member]	Louisiana Public Service Commission [Member]
					2010 FRP [Member]	2013 FRP Monitoring Report [Member]
Public Utilities, General Disclosures [Line Items]	'	'	'	'	'	'
Target return on equity allowed by FRP (in thousandths)	'	'	'	'	10.70%	'
Percentage of retail earnings within range to be returned to customers (in hundredths)	'	'	'	'	60.00%	'
Return on equity for customer credit, low range (in thousandths)	'	'	'	'	11.30%	'
Return on equity for customer credit, high range (in thousandths)	'	'	'	'	12.30%	'
Total amount to be returned to customers, as indicated on the filed monitoring report	'	'	'	'	'	$2,200,000
Provision for rate refund	$3,720,000	$3,533,000	$3,720,000	$3,533,000	'	'

Variable_Interest_Entities_Det

Variable Interest Entities (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013	Dec. 31, 2013
Components of equity method investments [Abstract]	'	'	'
Total equity investment in investee	$14,540	'	$14,540
Oxbow 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%	'	'
Components of equity method investments [Abstract]	'	'	'
Purchase price	12,873	'	12,873
Cash contributions	1,659	'	1,659
Total equity investment in investee	14,532	'	14,532
Comparison of carrying amount of assets and liabilities to maximum loss exposure [Abstract]	'	'	'
Oxbow's net assets/liabilities	29,065	'	29,065
Cleco Power's 50% equity	14,532	'	14,532
Cleco's maximum exposure to loss	14,532	'	14,532
Summarized financial information [Abstract]	'	'	'
Current assets	2,303	'	2,289
Property, plant and equipment, net	22,587	'	22,611
Other assets	4,248	'	4,256
Total assets	29,138	'	29,156
Current liabilities	61	'	91
Other liabilities	12	'	0
Partner's capital	29,065	'	29,065
Total liabilities and partners' capital	29,138	'	29,156
Operating revenue	585	429	'
Operating expenses	585	429	'
Income (loss) before taxes	0	0	'
Maximum [Member] | Subsidiaries Less Than 100% Owned by Diversified Lands LLC, Not Primary Beneficiary [Member]	'	'	'
Components of equity method investments [Abstract]	'	'	'
Total equity investment in investee	$100	'	'

Litigation_Other_Commitments_a2

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Litigation (Details) (USD $)	3 Months Ended		12 Months Ended			1 Months Ended
In Millions, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2014	Dec. 31, 2010	Dec. 31, 2009	Mar. 09, 2010	Mar. 31, 2010	Mar. 31, 2010
	Discrimination Complaint [Member]	Other Litigation Matters [Member]	Minimum [Member]	Minimum [Member]	Cleco Power [Member]	Cleco Power [Member]	Cleco Power [Member]
	plaintiff		Discrimination Complaint [Member]	Discrimination Complaint [Member]	City of Opelousas Litigation [Member]	Minimum [Member]	Customer [Member]
					claim	City of Opelousas Litigation [Member]	City of Opelousas Litigation [Member]
					resident		customer
Litigation [Abstract]	'	'	'	'	'	'	'
Loss contingency, damages sought, minimum amount	'	'	$2.50	$35	'	$30	'
Loss contingency, number of plaintiffs (in ones)	1	'	'	'	'	'	3
Number of residents in second class action lawsuit (in ones)	'	'	'	'	249	'	'
Number of class action law suits (in ones)	'	'	'	'	2	'	'
Amount of estimated loss	'	$10.50	'	'	'	'	'

Litigation_Other_Commitments_a3

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Off-Balance Sheet Commitments (Details) (USD $)

Mar. 31, 2014

Mar. 31, 2014

Jan. 31, 2006

Mar. 31, 2014

Dec. 05, 2013

Mar. 31, 2014

Aug. 31, 2011

Mar. 15, 2014

Mar. 15, 2014

Mar. 15, 2014

Mar. 15, 2014

Apr. 08, 2014

Mar. 31, 2014

In Thousands, unless otherwise specified

Cleco Power [Member]

Attala [Member]

Attala [Member]

MISO [Member]

MISO [Member]

Louisiana Department of Labor [Member]

Louisiana Department of Labor [Member]

Evangeline [Member]

Evangeline [Member]

Evangeline [Member]

Evangeline [Member]

Subsequent Event [Member]

Off-balance sheet commitments [Member]

Obligations Under Standby Letter of Credit [Member]

Parent Company [Member]

Parent Company [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Transfer of assets from affiliate [Member]

Transfer of assets from affiliate [Member]

Transfer of assets from affiliate [Member]

Transfer of assets from affiliate [Member]

MISO [Member]

Guarantee Issued to Entergy Mississippi on behalf of Attala [Member]

Guarantee Issued to Entergy Mississippi on behalf of Attala [Member]

Obligations Under Standby Letter of Credit [Member]

Obligations Under Standby Letter of Credit [Member]

Obligations Under Standby Letter of Credit [Member]

Obligations Under Standby Letter of Credit [Member]

Indemnification Agreement [Member]

Indemnification Agreement INCLUDING fundamental organizational structure [Member]

Cleco Power [Member]

Cleco Power [Member]

Cleco Power [Member]

Indemnification Agreement [Member]

Indemnification Agreement INCLUDING fundamental organizational structure [Member]

Obligations Under Standby Letter of Credit [Member]

Other Commitments [Line Items]

'

'

'

'

'

'

'

'

'

'

'

'

'

Face amount

'

$500

$500

$1,000

$1,000

$3,725

$3,725

$40,000

$400,000

$40,000

$400,000

$2,000

$5,225

Percentage of average losses on which letter of credit is based (in hundredths)

110.00%

'

'

'

'

'

'

'

'

'

'

'

'

Litigation_Other_Commitments_a4

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Disclosures about Guarantees (Details) (USD $)	1 Months Ended	3 Months Ended
	Apr. 30, 2011	Mar. 31, 2014	Mar. 31, 2013	Apr. 29, 2011
2004 sale of Perryville facility [Member] | Performance Guarantee [Member]	'	'	'	'
Disclosures about Guarantees [Abstract]	'	'	'	'
Guarantor Obligations, Maximum Exposure, Undiscounted	'	$42,400,000	'	'
Guarantor Obligations, Current Carrying Value	'	200,000	'	'
Acadia Unit 2 Transaction [Member] | Guarantee Issued to Cleco Power on behalf of Acadia [Member]	'	'	'	'
Disclosures about Guarantees [Abstract]	'	'	'	'
Guarantor Obligations, Maximum Exposure, Undiscounted	'	298,800,000	'	'
Guarantees, Fair Value Disclosure	'	'	'	21,800,000
Guarantor Obligations, Term	'P3Y	'	'	'
Maximum residual value of indemnification obligation	'	200,000	'	'
Guarantor Obligations, Current Carrying Value	'	900,000	'	'
Income from contractual expiration of indemnification	'	0	0	'
Off-balance sheet commitments [Member]	'	'	'	'
Disclosures about Guarantees [Abstract]	'	'	'	'
Guarantor Obligations, Maximum Exposure, Undiscounted	'	5,225,000	'	'
Amount of Commitment Expiration Per Period [Abstract]	'	'	'	'
Less than one year	'	3,725,000	'	'
1-3 Years	'	0	'	'
3-5 Years	'	1,000,000	'	'
More than 5 years	'	500,000	'	'
Total	'	5,225,000	'	'
On-balance sheet guarantees [Member]	'	'	'	'
Amount of Commitment Expiration Per Period [Abstract]	'	'	'	'
Less than one year	'	900,000	'	'
1-3 Years	'	0	'	'
3-5 Years	'	0	'	'
More than 5 years	'	4,006,000	'	'
Total	'	4,906,000	'	'
Off-balance sheet commitment and on-balance sheet guarantees [Member]	'	'	'	'
Amount of Commitment Expiration Per Period [Abstract]	'	'	'	'
Less than one year	'	4,625,000	'	'
1-3 Years	'	0	'	'
3-5 Years	'	1,000,000	'	'
More than 5 years	'	4,506,000	'	'
Total	'	10,131,000	'	'
Cleco Power [Member] | Lignite Mining Agreement Guarantee [Member] | Financial Guarantee [Member]	'	'	'	'
Disclosures about Guarantees [Abstract]	'	'	'	'
Guarantor Obligations, Maximum Exposure, Undiscounted	'	98,100,000	'	'
Guarantor Obligations, Current Carrying Value	'	$3,800,000	'	'

Litigation_Other_Commitments_a5

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Other Commitments (Details) (New Markets Tax Credit [Member], USD $)	3 Months Ended
	Mar. 31, 2014	Aug. 31, 2008
New Markets Tax Credit [Member]	'	'
Other Commitments [Line Items]	'	'
Membership interest in U.S Bank New Markets Tax Credit Fund (in thousandths)	'	99.90%
Equity contributions to be made to the Fund	$283,600,000	'
Net tax benefits to be received from the Fund	301,900,000	'
Difference between equity contributions and total benefits received will be recognized over the life of the Fund as net tax benefits	18,300,000	'
Future equity contributions to the NMTC Fund [Abstract]	'	'
Nine months ending Dec. 31, 2014	36,252,000	'
Year ending Dec. 31, 2015	11,195,000	'
Year ending Dec. 31, 2016	3,698,000	'
Year ending Dec. 31, 2017	2,913,000	'
Total	54,058,000	'
Total future equity contributions	54,058,000	'
Future equity contributions due within the next 12 months	38,400,000	'
Tax benefits in excess of capital contributions	62,400,000	'
Tax benefits not utilized	112,900,000	'
Equity contributions with an imputed interest rate [Abstract]	'	'
Equity contributions - imputed interst rate (in hundredths)	6.00%	'
Principal payment schedule above:	54,058,000	'
Less: unamortized discount	3,011,000	'
Total	$51,047,000	'
Period of recognition of gross investment amortization expense (in years)	'9 years	'
Remaining period of recognition of gross investment amortization expense (in years)	'4 years	'

Affiliate_Transactions_Details

Affiliate Transactions (Details) (Cleco Power [Member], USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Related Party Transaction [Line Items]	'	'
Accounts payable - affiliate	$7,793	$8,386
Accounts receivable - affiliate	2,932	1,045
Cleco Corporation [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable - affiliate	712	389
Accounts receivable - affiliate	1,773	379
Support Group [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable - affiliate	6,203	5,972
Accounts receivable - affiliate	853	634
Midstream [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable - affiliate	11	1
Accounts receivable - affiliate	265	27
Evangeline [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable - affiliate	867	2,024
Accounts receivable - affiliate	38	4
Diversified Lands [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable - affiliate	0	0
Accounts receivable - affiliate	1	1
Others [Member]	'	'
Related Party Transaction [Line Items]	'	'
Accounts payable - affiliate	0	0
Accounts receivable - affiliate	$2	$0

Accumulated_Other_Comprehensiv2

Accumulated Other Comprehensive Loss (Details) (USD $)	3 Months Ended
In Thousands, unless otherwise specified	Mar. 31, 2014	Mar. 31, 2013
Accumulated Other Comprehensive Loss [Line Items]	'	'
Accumulated other comprehensive loss, Beginning Balance	($25,876)	($32,370)
Other comprehensive income before reclassifications:	0	1,355
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	844	536
Net current-period other comprehensive income	897	1,873
Accumulated other comprehensive loss, Ending Balance	-24,979	-30,497
Regulatory Asset [Member]	'	'
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	0	-30
Interest Expense [Member]	'	'
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	53	12
Postretirement Benefit Net Loss [Member]	'	'
Accumulated Other Comprehensive Loss [Line Items]	'	'
Accumulated other comprehensive loss, Beginning Balance	-19,725	-24,741
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	844	536
Net current-period other comprehensive income	844	536
Accumulated other comprehensive loss, Ending Balance	-18,881	-24,205
Net Loss on Cash Flow Hedges [Member]	'	'
Accumulated Other Comprehensive Loss [Line Items]	'	'
Accumulated other comprehensive loss, Beginning Balance	-6,151	-7,629
Other comprehensive income before reclassifications:	0	1,355
Net current-period other comprehensive income	'	'
Net current-period other comprehensive income	53	1,337
Accumulated other comprehensive loss, Ending Balance	-6,098	-6,292
Net Loss on Cash Flow Hedges [Member] | Regulatory Asset [Member]	'	'
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	0	-30
Net Loss on Cash Flow Hedges [Member] | Interest Expense [Member]	'	'
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	53	12
Cleco Power [Member]	'	'
Accumulated Other Comprehensive Loss [Line Items]	'	'
Accumulated other comprehensive loss, Beginning Balance	-15,177	-20,421
Other comprehensive income before reclassifications:	0	1,355
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	525	251
Net current-period other comprehensive income	578	1,588
Accumulated other comprehensive loss, Ending Balance	-14,599	-18,833
Cleco Power [Member] | Regulatory Asset [Member]	'	'
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	0	-30
Cleco Power [Member] | Interest Expense [Member]	'	'
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	53	12
Cleco Power [Member] | Postretirement Benefit Net Loss [Member]	'	'
Accumulated Other Comprehensive Loss [Line Items]	'	'
Accumulated other comprehensive loss, Beginning Balance	-9,026	-12,792
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	525	251
Net current-period other comprehensive income	525	251
Accumulated other comprehensive loss, Ending Balance	-8,501	-12,541
Cleco Power [Member] | Net Loss on Cash Flow Hedges [Member]	'	'
Accumulated Other Comprehensive Loss [Line Items]	'	'
Accumulated other comprehensive loss, Beginning Balance	-6,151	-7,629
Other comprehensive income before reclassifications:	0	1,355
Net current-period other comprehensive income	'	'
Net current-period other comprehensive income	53	1,337
Accumulated other comprehensive loss, Ending Balance	-6,098	-6,292
Cleco Power [Member] | Net Loss on Cash Flow Hedges [Member] | Regulatory Asset [Member]	'	'
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	0	-30
Cleco Power [Member] | Net Loss on Cash Flow Hedges [Member] | Interest Expense [Member]	'	'
Net current-period other comprehensive income	'	'
Amounts reclassified from accumulated other comprehensive income, net of tax	$53	$12

Coughlin_Transfer_Coughlin_Tra1

Coughlin Transfer Coughlin Transfer (Details) (USD $)	Mar. 31, 2014	Dec. 31, 2013
In Thousands, unless otherwise specified
Related Party [Line Items]	'	'
Public Utilities, Property, Plant and Equipment, Net	$2,955,036	$2,975,299
Cleco Power [Member]	'	'
Related Party [Line Items]	'	'
Public Utilities, Property, Plant and Equipment, Net	2,949,237	2,791,931
Transfer of assets from affiliate [Member] | Evangeline [Member] | Cleco Power [Member]	'	'
Related Party [Line Items]	'	'
Public Utilities, Property, Plant and Equipment, Net	$176,000	'