10-Q

UNITED STATES SECURITIES AND EXCHANGE COMMISSION

Washington, D.C.  20549

FORM 10-Q

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

For the quarterly period ended September 30, 2012

Or

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

Commission file number 1-15759

CLECO CORPORATION

(Exact name of registrant as specified in its charter)

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

Commission file number 1-05663

CLECO POWER LLC

(Exact name of registrant as specified in its charter)

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

Number of shares outstanding of each of Cleco Corporation’s classes of Common Stock, as of the latest practicable date.

Registrant	Description of Class	Shares Outstanding at October 26, 2012
Cleco Corporation	Common Stock, $1.00 Par Value	60,726,390

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

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

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

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

TABLE OF CONTENTS

		PAGE
GLOSSARY OF TERMS		3
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS		5
PART I	Financial Information
ITEM 1.	Cleco Corporation — Condensed Consolidated Financial Statements	7
	Cleco Power — Condensed Consolidated Financial Statements	16
	Notes to the Unaudited Condensed Consolidated Financial Statements	24
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	44
ITEM 3.	Quantitative and Qualitative Disclosures about Market Risk	59
ITEM 4.	Controls and Procedures	60
PART II	Other Information
ITEM 1.	Legal Proceedings	61
ITEM 1A.	Risk Factors	61
ITEM 4.	Mine Safety Disclosures	61
ITEM 5.	Other Information	61
ITEM 6.	Exhibits	62
	Signatures	63

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

GLOSSARY OF TERMS

References in this filing, including all items in Parts I and II, to “Cleco” mean Cleco Corporation and its subsidiaries, including Cleco Power, and references to “Cleco Power” mean Cleco Power LLC and its subsidiaries, unless the context clearly indicates otherwise. Additional abbreviations or acronyms used in this filing, including all items in Parts I and II are defined below.

ABBREVIATION OR ACRONYM	DEFINITION
401(k) Plan	Cleco Power 401(k) Savings and Investment Plan
ABR	Alternate Base Rate
Acadia	Acadia Power Partners, LLC, a wholly owned subsidiary of APH.  Acadia no longer owns any materials and supply inventory, property, plant, and equipment, or land as a result of the disposition of Acadia Unit 2 to Entergy Louisiana on April 29, 2011.  From February 23, 2010 to April 29, 2011, Acadia was owned 100% by Cajun and consisted of Acadia Unit 2.  Prior to February 23, 2010, Acadia was 50% owned by APH and 50% owned by Cajun and consisted of Acadia Unit 1 and Acadia Unit 2.
Acadia Unit 1	Cleco Power’s 580-MW unit, combined cycle, natural gas-fired power plant located at the Acadia Power Station near Eunice, Louisiana. Prior to February 2010, Acadia Unit 1 was owned by Acadia.
Acadia Unit 2	Entergy Louisiana’s 580-MW unit, combined cycle, natural gas-fired power plant located at the Acadia Power Station near Eunice, Louisiana.  Prior to April 29, 2011, Acadia Unit 2 was owned by Acadia.
Acadiana Load Pocket	An area in south central Louisiana that has experienced transmission constraints caused by local load and lack of generation.  Transmission within the Acadiana Load Pocket is owned by several entities, including Cleco Power.
AFUDC	Allowance for Funds Used During Construction
Amended Lignite Mining Agreement	Amended and restated lignite mining agreement effective December 29, 2009
AMI	Advanced Metering Infrastructure
APH	Acadia Power Holdings LLC, a wholly owned subsidiary of Midstream
Attala	Attala Transmission LLC, a wholly owned subsidiary of Cleco Corporation
Cajun	Cajun Gas Energy L.L.C.  In conjunction with the disposition of Acadia Unit 2 on April 29, 2011, APH no longer has any ownership interest in Cajun.  From February 23, 2010 to April 29, 2011, Cajun was 50% owned by APH and 50% owned by third parties.  Prior to February 23, 2010, Cajun was 100% owned by third parties.
CERCLA	The Comprehensive Environmental Response, Compensation, and Liability Act of 1980
Cleco Innovations LLC	A wholly owned subsidiary of Cleco Corporation
Cleco Katrina/Rita	Cleco Katrina/Rita Hurricane Recovery Funding LLC, a wholly owned subsidiary of Cleco Power
Coughlin	Coughlin Power Station, a combined-cycle, natural gas-fired power plant located in Evangeline Parish, Louisiana.
CSAPR	The Cross-State Air Pollution Rule
DHLC	Dolet Hills Lignite Company, LLC, a wholly owned subsidiary of SWEPCO
Diversified Lands	Diversified Lands LLC, a wholly owned subsidiary of Cleco Innovations LLC
Dodd-Frank Act	The Dodd-Frank Wall Street Reform and Consumer Protection Act, signed into law on July 21, 2010.
DOE	United States Department of Energy
Entergy Gulf States	Entergy Gulf States Louisiana, L.L.C., formerly Entergy Gulf States, Inc.
Entergy Louisiana	Entergy Louisiana, LLC
Entergy Mississippi	Entergy Mississippi, Inc.
Entergy Services	Entergy Services, Inc., as agent for Entergy Louisiana and Entergy Gulf States
EPA	United States Environmental Protection Agency
ESPP	Cleco Corporation Employee Stock Purchase Plan
Evangeline	Cleco Evangeline LLC, a wholly owned subsidiary of Midstream
Evangeline 2010 Tolling Agreement	Capacity Sale and Tolling Agreement between Evangeline and JPMVEC, which was executed in February 2010 and expired on December 31, 2011
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
FRP	Formula Rate Plan
GAAP	Generally Accepted Accounting Principles in the United States
GO Zone	Gulf Opportunity Zone Act of 2005 (Public Law 109-135)
ICT	Independent Coordinator of Transmission
Interconnection Agreement	One of two Interconnection Agreement and Real Estate Agreements, one between Attala and Entergy Mississippi, and the other between Perryville and Entergy Louisiana
IRP	Integrated Resource Planning
IRS	Internal Revenue Service
JPMVEC	J.P. Morgan Ventures Energy Corporation.  In September 2008, BE Louisiana LLC (an indirect wholly owned subsidiary of JPMorgan Chase & Co.) was merged into JPMVEC.
kWh	Kilowatt-hour(s) as applicable
LIBOR	London Inter-Bank Offer Rate
Lignite Mining Agreement	Dolet Hills Mine Lignite Mining Agreement, dated May 31, 2001

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

ABBREVIATION OR ACRONYM	DEFINITION
LPSC	Louisiana Public Service Commission
LTICP	Cleco Corporation Long-Term Incentive Compensation Plan
Madison Unit 3	A 600-MW solid-fuel generating unit at Cleco Power’s plant site in Boyce, Louisiana that commenced commercial operation on February 12, 2010.
Midstream	Cleco Midstream Resources LLC, a wholly owned subsidiary of Cleco Corporation
MMBtu	Million British thermal units
Moody’s	Moody’s Investors Service
MW	Megawatt(s) as applicable
NERC	North American Electric Reliability Corporation
NMTC Fund	USB NMTC Fund 2008-1 LLC was formed to invest in projects qualifying for New Markets Tax Credits and Solar Projects
Not Meaningful	A percentage comparison of these items is not statistically meaningful because the percentage difference is greater than 1,000%
NOx	Nitrogen oxides
OCI	Other Comprehensive Income
Oxbow	Oxbow Lignite Company, LLC, 50% owned by Cleco Power and 50% owned by SWEPCO
PCAOB	Public Company Accounting Oversight Board
PCB	Polychlorinated biphenyl
Perryville	Perryville Energy Partners, L.L.C., a wholly owned subsidiary of Cleco Corporation
Power Purchase Agreement	Power Purchase Agreement, dated as of January 28, 2004, between Perryville and Entergy Services
PPACA	Patient Protection and Affordable Care Act (HR 3590)
Registrant(s)	Cleco Corporation and Cleco Power
RFP	Request for Proposal
RTO	Regional Transmission Organization
Sale Agreement	Purchase and Sale Agreement, dated as of January 28, 2004, between Perryville and Entergy Louisiana
SEC	Securities and Exchange Commission
SERP	Cleco Corporation Supplemental Executive Retirement Plan
SPP	Southwest Power Pool
Support Group	Cleco Support Group LLC, a wholly owned subsidiary of Cleco Corporation
SWEPCO	Southwestern Electric Power Company, a wholly owned subsidiary of American Electric Power Company, Inc.
VaR	Value-at-risk
VIE	Variable Interest Entity

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

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

• factors affecting utility operations, such as unusual weather conditions or other natural phenomena, catastrophic weather-related damage (such as hurricanes and other storms or severe drought conditions), unscheduled generation outages, unanticipated maintenance or repairs, unanticipated changes to fuel costs, fuel supply costs or availability constraints due to higher demand, shortages, transportation problems, or other developments, fuel mix of Cleco’s generation facilities, decreased customer load, environmental incidents, environmental compliance costs, and power transmission system constraints,

• Cleco Corporation’s holding company structure and its dependence on the earnings, dividends, or distributions from its subsidiaries to meet its debt obligations and pay dividends on its common stock,

• Cleco Power’s ability to recover costs incurred on projects funded, in whole or in part, through government grants,

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

• dependence of Cleco Power for energy from sources other than its facilities and the uncertainty of future sources of such additional energy,

• nonperformance by and creditworthiness of counterparties under power purchase agreements, or the restructuring of those agreements, including possible termination,

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

• regulatory factors such as changes in rate-setting policies, recovery of investments made under traditional regulation, recovery of storm restoration costs, the frequency and timing of rate increases or decreases, the results of periodic NERC

and LPSC audits, the formation of ICTs, including possible participation in an RTO and Cleco Power’s ability to recover related transmission upgrade costs, and the compliance with the Electric Reliability Organization reliability standards for bulk power systems by Cleco Power and Evangeline,

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

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

• the current global and U.S. economic environment,

• credit ratings of Cleco Corporation and Cleco Power,

• ability to remain in compliance with debt covenants,

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

• the availability and use of alternative sources of energy and technologies,

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

• reliability of Cleco Power and Midstream generating facilities,

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

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

• changes in tax laws or disallowances of uncertain tax positions that may result in a change to tax benefits or expenses,

• employee work force factors, including work stoppages and changes in key executives,

• legal, environmental, and regulatory delays and other obstacles associated with mergers, acquisitions, reorganizations, investments in joint ventures, or other capital projects, including the joint project to upgrade the Acadiana Load Pocket transmission system and the AMI project,

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

• changes in federal, state, or local laws and changes in tax laws or rates, or regulating policies,

• the impact of current or future environmental laws and regulations, including those related to greenhouse gases

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

and energy efficiency, which could limit or terminate the operation of certain generating units, increase costs, reduce customer demand for electricity, or otherwise materially adversely impact the Registrants’ financial condition or results of operations,

• ability of Cleco Power to recover from its customers the costs of compliance with environmental laws and regulations, and

• ability of Dolet Hills lignite reserve to provide sufficient fuel to the Dolet Hills Power Station until at least 2026.

For more discussion of these factors and other factors that could cause actual results to differ materially from those contemplated in the Registrants’ forward-looking statements, please read "Risk Factors" in this report and the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011. All subsequent written and oral forward-looking statements attributable to the Registrants or persons acting on their behalf are expressly qualified in their entirety by the factors identified above.

The Registrants undertake no obligation to update any forward-looking statements, whether as a result of changes in actual results, changes in assumptions, or other factors affecting such statements.

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

PART I — FINANCIAL INFORMATION

ITEM 1.  CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Cleco Corporation

These unaudited condensed consolidated financial statements should be read in conjunction with Cleco Corporation’s Consolidated Financial Statements and Notes included in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011. For more information on the basis of presentation, see “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — Basis of Presentation.”

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO CORPORATION
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS, EXCEPT SHARE AND PER SHARE AMOUNTS)	2012			2011
Operating revenue
Electric operations	$	282,894		$	324,532
Tolling operations	—			9,133
Other operations	15,408			16,064
Gross operating revenue	298,302			349,729
Electric customer credits	(930		)	1,852
Operating revenue, net	297,372			351,581
Operating expenses
Fuel used for electric generation	79,701			122,774
Power purchased for utility customers	19,364			25,473
Other operations	30,517			32,138
Maintenance	20,059			14,587
Depreciation	34,931			31,237
Taxes other than income taxes	9,455			9,845
(Gain) loss on sale of assets	(2		)	27
Total operating expenses	194,025			236,081
Operating income	103,347			115,500
Interest income	132			509
Allowance for other funds used during construction	1,882			902
Equity loss from investees, before tax	—			(1		)
Other income	1,834			2,128
Other expense	(1,232		)	(2,680		)
Interest charges
Interest charges, including amortization of debt expense, premium, and discount, net	22,610			26,105
Allowance for borrowed funds used during construction	(644		)	(326		)
Total interest charges	21,966			25,779
Income before income taxes	83,997			90,579
Federal and state income tax expense	20,179			24,737
Net income applicable to common stock	$	63,818		$	65,842
Average number of basic common shares outstanding	60,346,476			60,467,595
Average number of diluted common shares outstanding	60,599,203			60,873,311
Basic earnings per share
Net income applicable to common stock	$	1.06		$	1.09
Diluted earnings per share
Net income applicable to common stock	$	1.05		$	1.08
Cash dividends paid per share of common stock	$	0.3375		$	0.28
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO CORPORATION
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011
Net income	$	63,818		$	65,842
Other comprehensive income (loss), net of tax:
Amortization of postretirement benefit net loss (net of tax expense of $239 in 2012 and $178 in 2011)	332			269
Cash flow hedges:
Net derivative gain (loss) (net of tax expense of $309 in 2012 and tax benefit of $11,529 in 2011)	493			(18,433		)
Reclassification of net gain to interest charges (net of tax benefit of $7 in 2012 $34 in 2011)	(10		)	(55		)
Total other comprehensive income (loss), net of tax	815			(18,219		)
Comprehensive income, net of tax	$	64,633		$	47,623
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO CORPORATION
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS, EXCEPT SHARE AND PER SHARE AMOUNTS)	2012			2011
Operating revenue
Electric operations	$	720,776		$	823,484
Tolling operations	—			16,137
Other operations	38,464			41,775
Affiliate revenue	—			202
Gross operating revenue	759,240			881,598
Electric customer credits	1,025			(3,405		)
Operating revenue, net	760,265			878,193
Operating expenses
Fuel used for electric generation	207,764			298,009
Power purchased for utility customers	44,069			60,590
Other operations	86,901			90,281
Maintenance	61,478			59,666
Depreciation	99,028			91,749
Taxes other than income taxes	29,198			28,770
Gain on sale of assets	(57		)	(468		)
Total operating expenses	528,381			628,597
Operating income	231,884			249,596
Interest income	163			794
Allowance for other funds used during construction	4,298			3,757
Equity income from investees, before tax	1			62,051
Other income	24,223			3,330
Other expense	(2,718		)	(2,861		)
Interest charges
Interest charges, including amortization of debt expense, premium, and discount, net	64,671			79,368
Allowance for borrowed funds used during construction	(1,466		)	(1,357		)
Total interest charges	63,205			78,011
Income before income taxes	194,646			238,656
Federal and state income tax expense	54,110			73,451
Net income	140,536			165,205
Preferred dividends requirements	—			26
Preferred stock redemption costs	—			112
Net income applicable to common stock	$	140,536		$	165,067
Average number of basic common shares outstanding	60,375,538			60,549,860
Average number of diluted common shares outstanding	60,626,471			60,830,251
Basic earnings per share
Net income applicable to common stock	$	2.33		$	2.73
Diluted earnings per share
Net income applicable to common stock	$	2.32		$	2.71
Cash dividends paid per share of common stock	$	0.9625		$	0.81
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO CORPORATION
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011
Net income	$	140,536		$	165,205
Other comprehensive income (loss), net of tax:
Amortization of postretirement benefit net loss (net of tax expense of $670 in 2012 and $454 in 2011)	1,221			910
Cash flow hedges:
Net derivative loss (net of tax benefit of $282 in 2012 and $11,529 in 2011)	(451		)	(18,433		)
Reclassification of net loss (gain) to interest charges (net of tax expense of $15 in 2012 and tax benefit of $103 in 2011)	24			(164		)
Reclassification of ineffectiveness to regulatory asset (net of tax expense of $982 in 2012)	1,570			—
Total other comprehensive income (loss), net of tax	2,364			(17,687		)
Comprehensive income, net of tax	$	142,900		$	147,518
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO CORPORATION
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Assets
Current assets
Cash and cash equivalents	$	68,364		$	93,576
Restricted cash and cash equivalents	3,406			8,761
Customer accounts receivable (less allowance for doubtful accounts of $1,031 in 2012 and $1,128 in 2011)	47,635			37,813
Other accounts receivable (less allowance for doubtful accounts of $26 in 2012 and $8 in 2011)	36,334			42,051
Taxes receivable	8,353			44,584
Unbilled revenue	31,505			30,129
Fuel inventory, at average cost	53,290			41,845
Material and supplies inventory, at average cost	58,212			53,714
Accumulated deferred federal and state income taxes, net	75,693			29,249
Accumulated deferred fuel	1,715			2,136
Cash surrender value of company-/trust-owned life insurance policies	56,647			51,073
Prepayments	5,095			5,384
Regulatory assets - other	12,810			13,028
Other current assets	398			3,442
Total current assets	459,457			456,785
Property, plant, and equipment
Property, plant, and equipment	4,082,636			4,023,655
Accumulated depreciation	(1,291,862		)	(1,230,783		)
Net property, plant, and equipment	2,790,774			2,792,872
Construction work in progress	183,529			101,027
Total property, plant, and equipment, net	2,974,303			2,893,899
Equity investment in investees	14,541			14,540
Prepayments	4,139			4,770
Restricted cash and cash equivalents, less current portion	13,320			27,067
Restricted investments	4,470			—
Regulatory assets and liabilities - deferred taxes, net	219,433			214,421
Regulatory assets - other	258,344			269,444
Net investment in direct financing lease	13,546			13,633
Intangible asset	123,608			133,595
Other deferred charges	21,732			22,048
Total assets	$	4,106,893		$	4,050,202
The accompanying notes are an integral part of the condensed consolidated financial statements.

(Continued on next page)

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO CORPORATION
Condensed Consolidated Balance Sheets (Unaudited) (Continued)
(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Liabilities and shareholders’ equity
Liabilities
Current liabilities
Long-term debt due within one year	$	90,937		$	24,258
Accounts payable	104,435			129,308
Customer deposits	45,197			43,091
Provision for rate refund	2,526			7,323
Interest accrued	27,249			22,642
Energy risk management liabilities, net	—			5,336
Interest rate risk management liability	4,063			3,330
Regulatory liabilities - other	8,251			33,019
Deferred compensation	9,604			8,302
Uncertain tax positions	31			27,239
Other current liabilities	17,559			17,154
Total current liabilities	309,852			321,002
Deferred credits
Accumulated deferred federal and state income taxes, net	760,602			649,926
Accumulated deferred investment tax credits	6,547			7,432
Postretirement benefit obligations	138,414			133,274
Regulatory liabilities - other	—			7,303
Restricted storm reserve	16,019			24,880
Uncertain tax positions	2,184			23,494
Tax credit fund investment, net	85,307			61,507
Contingent sale obligations	10,350			29,357
Other deferred credits	38,580			35,114
Total deferred credits	1,058,003			972,287
Long-term debt, net	1,237,184			1,337,056
Total liabilities	2,605,039			2,630,345
Commitments and Contingencies (Note 11)
Shareholders’ equity
Common shareholders’ equity
Common stock, $1 par value, authorized 100,000,000 shares, issued 60,956,882 and 60,702,342 shares and outstanding 60,350,481 and 60,291,939 shares at September 30, 2012, and December 31, 2011, respectively	60,957			60,702
Premium on common stock	415,289			409,904
Retained earnings	1,072,468			990,605
Treasury stock, at cost, 606,401 and 410,403 shares at September 30, 2012, and December 31, 2011, respectively	(21,085		)	(13,215		)
Accumulated other comprehensive loss	(25,775		)	(28,139		)
Total shareholders’ equity	1,501,854			1,419,857
Total liabilities and shareholders’ equity	$	4,106,893		$	4,050,202
The accompanying notes are an integral part of the condensed consolidated financial statements.

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO CORPORATION
Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011
Operating activities
Net income	$	140,536		$	165,205
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	122,676			114,104
Return on equity investment in investees	—			58,665
Income from equity investments	(1		)	(62,051		)
Unearned compensation expense	4,986			6,065
Allowance for other funds used during construction	(4,298		)	(3,757		)
Net deferred income taxes	8,040			45,336
Deferred fuel costs	(4,218		)	(6,422		)
Cash surrender value of company-/trust-owned life insurance	(2,841		)	1,055
Changes in assets and liabilities:
Accounts receivable	(13,247		)	(21,691		)
Accounts and notes receivable, affiliate	257			1,074
Unbilled revenue	(1,376		)	11,538
Fuel, materials and supplies inventory	(15,943		)	40,675
Prepayments	920			2,089
Accounts payable	(25,422		)	(37,467		)
Customer deposits	8,772			9,718
Postretirement benefit obligations	5,459			(56,743		)
Regulatory assets and liabilities, net	(30,532		)	(40,204		)
Contingent sale obligations	—			10,900
Other deferred accounts	(17,388		)	2,181
Taxes accrued	36,021			12,946
Interest accrued	7,616			10,738
Energy risk management assets and liabilities, net	(28		)	3,880
Other operating	4,615			(4,244		)
Net cash provided by operating activities	224,604			263,590
Investing activities
Additions to property, plant, and equipment	(177,146		)	(146,617		)
Allowance for other funds used during construction	4,298			3,757
Property, plant, and equipment grants	15,075			1,593
Insurance reimbursement for property loss	5,454			—
Cash from reconsolidation of VIEs	—			3,879
Return of equity investment in investees	—			89,654
Return of equity investment in tax credit fund	37,132			244
Contributions to tax credit fund	(46,859		)	(18,479		)
Transfer of cash from restricted accounts	19,102			12,144
Purchase of restricted investments	(4,340		)	—
Other investing	(1,934		)	(1,220		)
Net cash used in investing activities	(149,218		)	(55,045		)

(Continued on next page)

14

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO CORPORATION
Condensed Consolidated Statements of Cash Flows (Unaudited) (Continued)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011
Financing activities
Retirement of short-term debt	—			(150,000		)
Draws on credit facility	—			10,000
Payments on credit facility	(10,000		)	(25,000		)
Issuance of long-term debt	50,000			—
Retirement of long-term debt	(74,368		)	(12,269		)
Repurchase of common stock	(8,007		)	(13,009		)
Dividends paid on common stock	(58,459		)	(49,170		)
Other financing	236			(1,993		)
Net cash used in financing activities	(100,598		)	(241,441		)
Net decrease in cash and cash equivalents	(25,212		)	(32,896		)
Cash and cash equivalents at beginning of period	93,576			191,128
Cash and cash equivalents at end of period	$	68,364		$	158,232
Supplementary cash flow information
Interest paid (net of amount capitalized)	$	48,212		$	53,936
Income taxes (refunded) paid, net	$	(131	)	$	18,241
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	16,657		$	11,491
Non-cash additions to property, plant, and equipment, net	$	18,395		$	6,252
Issuance of common stock – ESPP	$	257		$	241
The accompanying notes are an integral part of the condensed consolidated financial statements.

15

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

PART I — FINANCIAL INFORMATION

ITEM 1.CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

Cleco Power

These unaudited condensed consolidated financial statements should be read in conjunction with Cleco Power’s Consolidated Financial Statements and Notes included in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011. For more information on the basis of presentation, see “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 1 — Summary of Significant Accounting Policies — Basis of Presentation.”

16

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS, EXCEPT SHARE AND PER SHARE AMOUNTS)	2012			2011
Operating revenue
Electric operations	$	282,894		$	324,532
Other operations	14,905			15,565
Affiliate revenue	343			347
Gross operating revenue	298,142			340,444
Electric customer credits	(930		)	1,852
Operating revenue, net	297,212			342,296
Operating expenses
Fuel used for electric generation	79,701			122,774
Power purchased for utility customers	33,254			25,473
Other operations	29,063			30,451
Maintenance	16,095			15,768
Depreciation	33,199			29,539
Taxes other than income taxes	8,390			8,802
Gain on sale of assets	—			(6		)
Total operating expenses	199,702			232,801
Operating income	97,510			109,495
Interest income	129			276
Allowance for other funds used during construction	1,882			902
Other income	1,188			1,323
Other expense	(1,224		)	(1,201		)
Interest charges
Interest charges, including amortization of debt expense, premium, and discount, net	22,606			25,632
Allowance for borrowed funds used during construction	(644		)	(326		)
Total interest charges	21,962			25,306
Income before income taxes	77,523			85,489
Federal and state income tax expense	19,740			31,656
Net income	$	57,783		$	53,833
The accompanying notes are an integral part of the condensed consolidated financial statements.

17

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011
Net income	$	57,783		$	53,833
Other comprehensive income (loss), net of tax:
Amortization of postretirement benefit net loss (net of tax expense of $103 in 2012 and $99 in 2011)	124			146
Cash flow hedges:
Net derivative gain (loss) (net of tax expense of $309 in 2012 and tax benefit of $11,529 in 2011)	493			(18,433		)
Reclassification of net gain to interest charges (net of tax benefit of $7 in 2012 and $34 in 2011)	(10		)	(55		)
Total other comprehensive income (loss), net of tax	607			(18,342		)
Comprehensive income, net of tax	$	58,390		$	35,491
The accompanying notes are an integral part of the condensed consolidated financial statements.

18

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011
Operating revenue
Electric operations	$	720,776		$	823,484
Other operations	36,967			40,261
Affiliate revenue	1,030			1,041
Gross operating revenue	758,773			864,786
Electric customer credits	1,025			(3,405		)
Operating revenue, net	759,798			861,381
Operating expenses
Fuel used for electric generation	207,459			298,009
Power purchased for utility customers	65,493			60,590
Other operations	82,647			85,162
Maintenance	51,739			53,962
Depreciation	93,847			86,650
Taxes other than income taxes	26,004			25,585
Gain on sale of assets	(1		)	(7		)
Total operating expenses	527,188			609,951
Operating income	232,610			251,430
Interest income	153			557
Allowance for other funds used during construction	4,298			3,757
Other income	3,511			2,168
Other expense	(2,698		)	(2,391		)
Interest charges
Interest charges, including amortization of debt expense, premium, and discount, net	62,719			75,386
Allowance for borrowed funds used during construction	(1,466		)	(1,357		)
Total interest charges	61,253			74,029
Income before income taxes	176,621			181,492
Federal and state income tax expense	54,748			61,935
Net income	$	121,873		$	119,557
The accompanying notes are an integral part of the condensed consolidated financial statements.

19

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011
Net income	$	121,873		$	119,557
Other comprehensive income (loss), net of tax:
Amortization of postretirement benefit net loss (net of tax expense of $267 in 2012 and $227 in 2011)	555			519
Cash flow hedges:
Net derivative loss (net of tax benefit of $282 in 2012 and $11,529 in 2011)	(451		)	(18,433		)
Reclassification of net loss (gain) to interest charges (net of tax expense of $15 in 2012 and tax benefit of $103 in 2011)	24			(164		)
Reclassification of ineffectiveness to regulatory asset (net of tax expense of $982 in 2012)	1,570			—
Total other comprehensive income (loss), net of tax	1,698			(18,078		)
Comprehensive income, net of tax	$	123,571		$	101,479
The accompanying notes are an integral part of the condensed consolidated financial statements.

20

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Assets
Utility plant and equipment
Property, plant, and equipment	$	3,815,608		$	3,759,541
Accumulated depreciation	(1,209,401		)	(1,153,004		)
Net property, plant, and equipment	2,606,207			2,606,537
Construction work in progress	180,777			97,595
Total utility plant, net	2,786,984			2,704,132
Current assets
Cash and cash equivalents	50,578			67,458
Restricted cash and cash equivalents	3,406			8,761
Customer accounts receivable (less allowance for doubtful accounts of $1,031 in 2012 and $1,128 in 2011)	47,635			37,813
Accounts receivable - affiliate	3,373			2,405
Other accounts receivable (less allowance for doubtful accounts of $26 in 2012 and $8 in 2011)	35,969			35,618
Taxes receivable	—			3,197
Unbilled revenue	31,505			30,129
Fuel inventory, at average cost	53,290			41,845
Material and supplies inventory, at average cost	55,465			51,132
Accumulated deferred federal and state income taxes, net	74,116			19,829
Accumulated deferred fuel	1,715			2,136
Cash surrender value of company-owned life insurance policies	20,742			20,433
Prepayments	4,172			4,155
Regulatory assets - other	12,810			13,028
Other current assets	393			375
Total current assets	395,169			338,314
Equity investment in investee	14,532			14,532
Prepayments	4,139			4,770
Restricted cash and cash equivalents, less current portion	13,223			26,970
Restricted investments	4,470			—
Regulatory assets and liabilities - deferred taxes, net	219,433			214,421
Regulatory assets - other	258,344			269,444
Intangible asset	123,608			133,595
Other deferred charges	20,229			20,293
Total assets	$	3,840,131		$	3,726,471

(Continued on next page)

21

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Balance Sheets (Unaudited) (Continued)
(THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
Liabilities and member’s equity
Member’s equity	$	1,296,433	$	1,230,862
Long-term debt, net	1,237,184		1,327,056
Total capitalization	2,533,617		2,557,918
Current liabilities
Long-term debt due within one year	90,937		24,258
Accounts payable	96,370		115,091
Accounts payable - affiliate	10,069		9,311
Customer deposits	45,197		43,091
Provision for rate refund	2,526		7,323
Taxes payable	20,019		—
Interest accrued	28,806		22,540
Energy risk management liabilities, net	—		5,336
Interest rate risk management liability	4,063		3,330
Regulatory liabilities - other	8,251		33,019
Uncertain tax positions	—		27,465
Other current liabilities	13,580		11,193
Total current liabilities	319,818		301,957
Commitments and Contingencies (Note 11)
Deferred credits
Accumulated deferred federal and state income taxes, net	828,195		675,835
Accumulated deferred investment tax credits	6,547		7,432
Postretirement benefit obligations	98,450		94,147
Regulatory liabilities - other	—		7,303
Restricted storm reserve	16,019		24,880
Uncertain tax positions	222		19,906
Other deferred credits	37,263		37,093
Total deferred credits	986,696		866,596
Total liabilities and member’s equity	$	3,840,131	$	3,726,471
The accompanying notes are an integral part of the condensed consolidated financial statements.

22

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

CLECO POWER
Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011
Operating activities
Net income	$	121,873		$	119,557
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	102,724			95,482
Unearned compensation expense	1,327			1,768
Allowance for other funds used during construction	(4,298		)	(3,757		)
Net deferred income taxes	43,259			35,174
Deferred fuel costs	(4,218		)	(6,422		)
Cash surrender value of company-owned life insurance	(308		)	(277		)
Changes in assets and liabilities:
Accounts receivable	(13,807		)	(23,859		)
Accounts and notes receivable, affiliate	(762		)	68
Unbilled revenue	(1,376		)	11,538
Fuel, materials and supplies inventory	(15,778		)	40,946
Prepayments	614			1,858
Accounts payable	(20,474		)	(32,826		)
Accounts and notes payable, affiliate	(53		)	(1,386		)
Customer deposits	8,772			9,718
Postretirement benefit obligations	4,323			(58,259		)
Regulatory assets and liabilities, net	(30,532		)	(40,204		)
Other deferred accounts	(20,057		)	(1,996		)
Taxes accrued	23,194			21,680
Interest accrued	9,482			11,075
Energy risk management assets and liabilities, net	(28		)	3,880
Other operating	1,650			1,878
Net cash provided by operating activities	205,527			185,636
Investing activities
Additions to property, plant, and equipment	(173,268		)	(131,962		)
Allowance for other funds used during construction	4,298			3,757
Property, plant, and equipment grants	15,075			1,593
Transfer of cash from restricted accounts	19,102			12,144
Purchase of restricted investments	(4,340		)	—
Other investing	804			664
Net cash used in investing activities	(138,329		)	(113,804		)
Financing activities
Issuance of long-term debt	50,000			—
Retirement of long-term debt	(74,368		)	(12,269		)
Distribution to parent	(58,000		)	(100,000		)
Other financing	(1,710		)	(1,460		)
Net cash used in financing activities	(84,078		)	(113,729		)
Net decrease in cash and cash equivalents	(16,880		)	(41,897		)
Cash and cash equivalents at beginning of period	67,458			184,912
Cash and cash equivalents at end of period	$	50,578		$	143,015
Supplementary cash flow information
Interest paid (net of amount capitalized)	$	48,140		$	52,220
Income taxes (refunded) paid, net	$	(246	)	$	2,233
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	16,141		$	20,088
Non-cash additions to property, plant, and equipment, net	$	18,395		$	6,252
The accompanying notes are an integral part of the condensed consolidated financial statements.

23

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

Index to Applicable Notes to the Unaudited Condensed Consolidated Financial Statements of Registrants
Note 1	Summary of Significant Accounting Policies	Cleco Corporation and Cleco Power
Note 2	Recent Authoritative Guidance	Cleco Corporation and Cleco Power
Note 3	Regulatory Assets and Liabilities	Cleco Corporation and Cleco Power
Note 4	Fair Value Accounting	Cleco Corporation and Cleco Power
Note 5	Debt	Cleco Corporation and Cleco Power
Note 6	Pension Plan and Employee Benefits	Cleco Corporation and Cleco Power
Note 7	Income Taxes	Cleco Corporation and Cleco Power
Note 8	Disclosures about Segments	Cleco Corporation
Note 9	Electric Customer Credits	Cleco Corporation and Cleco Power
Note 10	Variable Interest Entities	Cleco Corporation and Cleco Power
Note 11	Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees	Cleco Corporation and Cleco Power
Note 12	Affiliate Transactions	Cleco Corporation and Cleco Power
Note 13	Acadia Unit 2 Transaction	Cleco Corporation and Cleco Power
Note 14	Storm Restoration	Cleco Corporation and Cleco Power
Note 15	Subsequent Event	Cleco Corporation and Cleco Power

Notes to the Unaudited Condensed Consolidated Financial Statements

Note 1 — Summary of Significant Accounting Policies

Principles of Consolidation

The accompanying condensed consolidated financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.

Basis of Presentation

The condensed consolidated financial statements of Cleco Corporation and Cleco Power have been prepared pursuant to the rules and regulations of the SEC. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted; however, Cleco believes that the disclosures are adequate to make the information presented not misleading.

The year-end condensed consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by GAAP. The unaudited financial information included in the condensed consolidated financial statements of Cleco Corporation and Cleco Power reflects all adjustments of a normal recurring nature which are, in the opinion of the management of Cleco Corporation and Cleco Power, necessary for a fair statement of the financial position and the results of operations for the interim periods. Information for interim periods is affected by seasonal variations in sales, rate changes, timing of fuel expense recovery, and other factors, and is not indicative necessarily of the results that may be expected for the full fiscal year. 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 consist 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. Property, plant, and equipment consisted of:

(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Regulated utility plants	$	3,815,608		$	3,759,541
Other	267,028			264,114
Total property, plant, and equipment	4,082,636			4,023,655
Accumulated depreciation	(1,291,862		)	(1,230,783		)
Net property, plant, and equipment	$	2,790,774		$	2,792,872

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 SEPT. 30, 2012		AT DEC. 31, 2011
Diversified Lands’ mitigation escrow	$	97	$	97
Cleco Katrina/Rita’s storm recovery bonds	3,406		8,761
Cleco Power’s future storm restoration costs	11,510		24,876
Cleco Power’s renewable energy grant	—		381
Cleco Power’s NOx allowance escrow	1,713		1,713
Total restricted cash and cash equivalents	$	16,726	$	35,828

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 operating expenses, interest, and principal on storm recovery bonds. During the nine months ended September 30, 2012, Cleco Katrina/Rita collected $14.7 million net of operating expenses. In March and September 2012, Cleco Katrina/Rita used $6.7 million and

24

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

$6.4 million, respectively for scheduled storm recovery bond principal payments and $3.6 million and $3.4 million, respectively for related interest. Cleco Power's restricted cash and cash equivalents held for future storm restoration costs decreased $13.4 million from December 31, 2011, primarily due to the transfer of $4.5 million to restricted investments and the transfer of $10.0 million to cover expenses associated with Hurricane Isaac. These amounts were partially offset by $1.1 million of storm surcredits. For more information about these restricted investments, see Note 4 — "Fair Value Accounting — Restricted Investments" and for more information about Hurricane Isaac, see Note 14 — "Storm Restoration."

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. Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the condensed consolidated balance sheets with their fair values as of the balance sheet date disclosed within the three levels. For more information about fair value levels, see Note 4 — “Fair Value Accounting.”

Risk Management

Market risk inherent in Cleco Power’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power and natural gas 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 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 enter into positions 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. When these positions close, actual gains or losses will be included in the fuel adjustment clause and reflected on customers’ bills as a component of the fuel cost adjustment.

Cleco Power maintains margin accounts with commodity brokers used to partially fund the acquisition of natural gas futures, options, and swap contracts. These contracts/positions are used to mitigate the risks associated with the volatility in customer fuel costs noted above. The current and long-term portions of collateral are reported as a component of energy risk management assets or liabilities and other deferred credits, respectively.

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 these contracts in which Cleco is hedging the variability of cash flows related to forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy, and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified as earnings in the periods in which earnings are affected by the variability of the cash flows of the hedged item. The ineffective portions of hedges will be recognized in current period earnings unless management determines that it is probable that the costs will be recovered through the rate-making process. If management determines that it is probable that the costs will be recovered, then they will be recognized as a regulatory asset or liability and amortized to earnings over the life of the related debt. For those contracts in which Cleco is hedging the variability of cash flows related to forecasted transactions that do not qualify as cash flow hedges, the changes in the fair value of such derivative instruments will be recognized in current period earnings unless management determines that it is probable that the costs will be recovered through the rate-making process. If management determines that it is probable that the costs will be recovered, then such costs will be recognized as a regulatory asset or liability and amortized to earnings over the life of the related debt. For more information on the interest rate risk contracts, see Note 4 — “Fair Value Accounting — Interest Rate Derivatives.”

Reclassifications

Certain reclassifications have been made to the 2011 financial statements to conform them to the presentation used in the 2012 financial statements. These reclassifications had no effect on Cleco Corporation’s net income applicable to common stock or total common shareholders’ equity or Cleco Power’s net income or total member’s equity.

During the second quarter of 2012, the Registrants began presenting the LPSC allowable portion of the amortization of the plant acquisition adjustment related to Acadia Unit 1 as depreciation expense on the Registrants’ Condensed Consolidated Statements of Income. Previously, this amortization was presented as other expense. The Registrants have reclassified prior year amounts to conform to this presentation. This change increased depreciation and decreased other expenses by $0.7 million and $2.1 million for the three and nine months ended September 30, 2011, respectively.

25

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

Also during the second quarter of 2012, the Registrants determined that an error existed in the statement of cash flows presentation of contributions received in aid of construction, specifically the impact that the accounting for these contributions had on the presentation of cash flows related to the additions of property, plant, and equipment. This caused errors between the operating activities section and investing activities section for prior periods.

Cleco and Cleco Power’s Condensed Consolidated Statements of Cash Flows for the nine months ended

September 30, 2011, have been adjusted to correct the presentation of cash flows related to additions to property, plant, and equipment. These corrections had no impact on the Registrants’ cash and cash equivalents, financial condition, or results of operations. Management believes that these corrections did not have a material effect on the Registrants’ Condensed Consolidated Statements of Cash Flows. The corrections to the September 30, 2011 Condensed Consolidated Statements of Cash Flows are presented in the following table:

				CLECO						CLECO POWER
	FOR THE NINE MONTHS ENDED SEPT. 30, 2011
(THOUSANDS)	AS REPORTED			AS ADJUSTED			AS REPORTED			AS ADJUSTED
Accounts receivable	$	(18,274	)	$	(21,691	)	$	(20,442	)	$	(23,859	)
Other deferred accounts	$	(2,184	)	$	2,181		$	(6,361	)	$	(1,996	)
Net cash provided by operating activities	$	262,642		$	263,590		$	184,688		$	185,636
Additions to property, plant, and equipment	$	(145,669	)	$	(146,617	)	$	(131,014	)	$	(131,962	)
Net cash used in investing activities	$	(54,097	)	$	(55,045	)	$	(112,856	)	$	(113,804	)
Net decrease in cash and cash equivalents	$	(32,896	)	$	(32,896	)	$	(41,897	)	$	(41,897	)
Cash and cash equivalents at the beginning of the period	$	191,128		$	191,128		$	184,912		$	184,912
Cash and cash equivalents at the end of the period	$	158,232		$	158,232		$	143,015		$	143,015

Earnings per Average Common Share

The following tables show the calculation of basic and diluted earnings per share:

						FOR THE THREE MONTHS ENDED SEPT. 30,
				2012					2011
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Basic net income applicable to common stock	$	63,818	60,346,476	$	1.06	$	65,842	60,467,595	$	1.09
Effect of dilutive securities
Add:  stock option grants			1,536					20,441
Add:  restricted stock (LTICP)			251,191					385,275
Diluted net income applicable to common stock	$	63,818	60,599,203	$	1.05	$	65,842	60,873,311	$	1.08

						FOR THE NINE MONTHS ENDED SEPT. 30,
				2012					2011
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Net income	$	140,536				$	165,205
Deduct:  non-participating stock dividends (4.5% preferred stock)	—					26
Deduct:  non-participating stock redemption costs (4.5% preferred stock)	—					112
Basic net income applicable to common stock	$	140,536	60,375,538	$	2.33	$	165,067	60,549,860	$	2.73
Effect of dilutive securities
Add:  stock option grants			4,518					20,965
Add:  restricted stock (LTICP)			246,415					259,426
Diluted net income applicable to common stock	$	140,536	60,626,471	$	2.32	$	165,067	60,830,251	$	2.71

Stock option grants are excluded from the computation of diluted earnings per share if the exercise price is higher than the average market price. There were no stock option grants excluded from the computation of diluted earnings per share for the three and nine months ended September 30, 2012 and 2011, due to the average market price being higher than the exercise prices of the stock options.

Stock-Based Compensation

At September 30, 2012, 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

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subsidiaries pursuant to the LTICP.

During the first quarter of 2012, Cleco granted 140,186 shares of non-vested stock to certain officers, key employees, and directors 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				CLECO CORPORATION				CLECO POWER
	FOR THE THREE MONTHS ENDED SEPT. 30,								FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011		2012		2011		2012		2011
Equity classification
Non-vested stock	$	1,139	$	1,095	$	301	$	225	$	3,271	$	3,042	$	792	$	748
Stock options	2		69		—		—		11		105		—		—
Total equity classification	$	1,141	$	1,164	$	301	$	225	$	3,282	$	3,147	$	792	$	748
Liability classification
Common stock equivalent units	$	847	$	1,024	$	338	$	435	$	1,552	$	2,583	$	631	$	1,020
Total pre-tax compensation expense	$	1,988	$	2,188	$	639	$	660	$	4,834	$	5,730	$	1,423	$	1,768
Tax benefit	$	765	$	842	$	246	$	254	$	1,860	$	2,205	$	548	$	680

Note 2 — Recent Authoritative Guidance

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

In April 2011, FASB issued guidance to improve the accounting for repurchase agreements and other similar agreements. Specifically, this guidance modifies the criteria for determining when these transactions would be accounted for as financings as opposed to sales or purchases with commitments to repurchase or resale. The adoption of this guidance was effective for the first period beginning on or after December 15, 2011. The adoption of this guidance did not have a material impact on the financial condition or results of operations of the Registrants.

In May 2011, FASB issued guidance on fair value measurements. This guidance results in a consistent definition of fair value and common requirements for measurement of and disclosure about fair value between GAAP and International Financial Reporting Standards. The adoption of this guidance is effective prospectively for interim and annual periods beginning after December 15, 2011. The adoption of this guidance did not have a material impact on the financial condition or results of operations of the Registrants.

In December 2011, FASB revised the disclosure requirements related to balance sheet offsetting. After the effective date, entities must disclose both the gross and net information about instruments and transactions eligible for offsetting on the balance sheet, including transactions under master netting agreements. The adoption of this revision is required for interim and annual periods beginning on or after January 1, 2013. The adoption of this revision will not have any effect on the financial condition or results of operations of the Registrants since it relates to disclosures.

In July 2012, FASB issued guidance on testing indefinite-lived intangible assets for impairment. This guidance is intended to reduce costs and complexity of testing indefinite-lived intangible assets other than goodwill for impairment. Entities are allowed to perform a “qualitative” assessment to determine whether further impairment testing of indefinite-lived intangible assets is necessary, similar in approach to the goodwill impairment test. The adoption of this guidance is effective for annual and interim impairment tests performed for fiscal years beginning after September 15, 2012. The adoption of this guidance will not have any impact on the financial condition or results of operations of the Registrants.

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 September 30, 2012 and December 31, 2011:

(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Regulatory assets – deferred taxes, net	$	219,433		$	214,421
Mining costs	$	17,206		$	19,117
Interest costs	6,394			6,667
Asset removal costs	851			829
Postretirement plan costs	126,349			132,556
Tree trimming costs	6,335			8,371
Training costs	7,369			7,486
Storm surcredits, net	5,958			9,254
Construction carrying costs	6,262			10,883
Lignite mining agreement contingency	3,781			3,781
Power purchase agreement capacity costs	5,921			—
AFUDC equity gross-up	73,906			74,346
Rate case costs	716			1,117
Acadia Unit 1 acquisition costs	2,892			2,971
IRP/RFP costs	156			508
AMI pilot costs	54			153
Financing costs	6,851			4,433
Biomass costs	153			—
Total regulatory assets – other	$	271,154		$	282,472
Construction carrying costs	(8,251		)	(40,322		)
Fuel and purchased power	1,715			2,136
Total regulatory assets, net	$	484,051		$	458,707

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 allows Cleco Power to defer and recover a portion of capacity costs associated with the power purchase agreement. The deferred costs will be collected over the term of the contract.

Financing Costs

In 2011, Cleco Power entered into and settled two treasury rate locks. Of the $26.8 million in settlements, $6.9 million was recorded as a regulatory asset relating to ineffectiveness of the

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hedge relationship. As a result of management’s assessment that it is probable that the ineffectiveness will be recovered through the rate-making process, Cleco Power will amortize the regulatory asset over the 30-year term of the related debt issuance.

Biomass Test Burn Costs

In November 2011, the LPSC approved Cleco Power’s request to establish a regulatory asset for the non-fuel, non-capital portion of costs incurred to conduct a test burn of biomass fuel at Madison Unit 3. These costs will be amortized over a five-year period.

Construction Carrying Costs

In February 2006, the LPSC approved Cleco Power’s plans to build Madison Unit 3. Terms of the approval included authorization for Cleco Power to collect from customers an amount equal to 75% of the LPSC-jurisdictional portion of the carrying costs of capital during the construction phase of the unit. Cleco Power’s retail rate plan, which was approved in October 2009, established that Cleco Power return carrying costs to customers and record a regulatory asset for all carrying costs incurred by Cleco Power above the actual

amount collected from customers. On February 12, 2010, Madison Unit 3 commenced commercial operations and Cleco Power began returning the construction carrying costs to customers. These costs are being amortized over a four-year period. As of September 30, 2012, Cleco Power had returned $158.2 million to customers. At September 30, 2012, $8.3 million was due to be returned to customers within one year.

Note 4 — Fair Value Accounting

The amounts reflected in Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2012 and December 31, 2011, for cash and cash equivalents, restricted cash and cash equivalents, accounts receivable, other accounts receivable, accounts payable, and short-term debt approximate fair value because of their short-term nature.  Estimates of the fair value of Cleco and Cleco Power’s long-term debt are based upon the quoted market price for the same or similar issues or by a discounted present value analysis of future cash flows using current rates obtained by Cleco and Cleco Power for debt with similar maturities. The following tables summarize the carrying value and estimated market value of Cleco and Cleco Power’s financial instruments subject to fair value accounting.

Cleco
	AT SEPT. 30, 2012				AT DEC. 31, 2011
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market
Cash and cash equivalents	$	68,364	$	68,364	$	93,576	$	93,576
Restricted cash and cash equivalents	$	16,726	$	16,726	$	35,828	$	35,828
Long-term debt, excluding debt issuance costs	$	1,320,198	$	1,553,694	$	1,354,567	$	1,542,867

Cleco Power
	AT SEPT. 30, 2012				AT DEC. 31, 2011
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market
Cash and cash equivalents	$	50,578	$	50,578	$	67,458	$	67,458
Restricted cash and cash equivalents	$	16,629	$	16,629	$	35,731	$	35,731
Long-term debt, excluding debt issuance costs	$	1,320,198	$	1,553,694	$	1,344,567	$	1,532,867

At September 30, 2012, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents and restricted cash equivalents. Cleco had $74.7 million ($58.5 million of cash equivalents and $16.2 million of restricted cash equivalents) in short-term investments in institutional money market funds. Cleco Power had $61.1 million ($45.0 million of cash equivalents and $16.1 million of restricted cash equivalents) in short-term investments in institutional money market funds. 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.

In May 2012, Cleco and Cleco Power revised their guidelines for short-term investments in order to mitigate credit risk. Qualifying investments include:

• U.S. treasury securities,

• U.S. federal agency and U.S. government-sponsored entity debt,

• Tax-exempt short-term securities of a state, territory,

or a possession of the U.S.,

• Certificates of deposit, banker's acceptances and time deposits,

• Corporate notes and bonds, fixed or floating rate, and covered bonds,

• Commercial paper,

• Asset backed securities with a minimum long-term rating of AA by Standard & Poor's and Aaa by Moody's,

• U.S. government mortgage securities with a short average life with a minimum long-term rating of AA by Standard & Poor's and Aaa by Moody's,

• Repurchase agreements with the primary government securities dealers or financial institutions in which Cleco deposits and/or concentrates cash, and

• Money market funds which must have at least $15.0 billion in assets under management; must have been in existence for not less than two years; must have a minimum rating of AAA by Standard & Poor's and Aaa by Moody's and must be compliant with the SEC rule 2a-7 which restricts the quality, maturity, and diversity of investments by money market funds.

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The minimum acceptable short-term credit rating must be A-1 by Standard & Poor's and P-1 by Moody's. The maximum maturity of any instrument must be 36 months, and the maximum portfolio duration must be 12 months.

Diversification of holdings must be stressed recognizing the total amount of the portfolio. Investments in securities of any one issuer will be limited to 5% at the time of purchase except for U.S. Treasury and Agency Securities and money market funds. No more than 50% of the portfolio at the time of purchase will be invested in any single Federal Agency/Government Sponsored Enterprise.

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 are restricted to the criteria established by management in Cleco Power's guidelines for short-term investments. At September 30, 2012, the investments included institutional money market funds and municipal bonds.

The institutional money market fund investments are reflected in Cleco and Cleco Power's Condensed Consolidated Balance Sheets at September 30, 2012, as restricted cash and cash equivalents and approximate fair value because of their short-term nature. 

The municipal bonds were recorded at fair value on Cleco and Cleco Power's Condensed Consolidated Balance Sheets at September 30, 2012, as restricted investments. The investments in municipal bonds are classified as available-for-sale securities and are marked-to-market at least quarterly. Because Cleco Power's investment strategy for these investments fits 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 are recorded directly to Cleco Power's restricted storm reserve rather than in earnings or other comprehensive income. As a result no amounts will be recorded to other comprehensive income for these investments.

Quarterly, Cleco Power's available-for-sale, debt securities are evaluated on an individual basis to determine if a decline

in fair value below the carrying value is other-than-temporary. Management determines whether it intends to sell or if it is more likely than not that it will be required to sell impaired securities. This determination considers current and forecasted liquidity and regulatory requirements. For Cleco Power's impaired debt securities for which there was no intent or expected requirement to sell, the evaluation assesses whether it is likely the amortized cost will be recovered considering the nature of the securities, credit rating, financial condition of the issuer or the extent and duration of the unrealized loss and market conditions. If Cleco Power determined that an other-than-temporary decline in value existed on its municipal bonds, the investments would be written down to fair value with a new cost basis established. Declines in fair value below cost basis that are determined to be other-than-temporary would be recorded to Cleco Power's restricted storm reserve. The unrealized losses on Cleco Power's municipal bonds as of September 30, 2012, were caused by interest rate movements. Cleco Power does not intend to sell the municipal bonds and has determined it is more likely than not that it will not be required to sell the investments before recovery of the amortized cost value. Cleco Power determined there were no material other-than-temporary impairments on its municipal bonds at September 30, 2012.

The following table provides a reconciliation of Cleco Power's available-for-sale securities from cost basis to fair value at September 30, 2012.

	AT SEPT. 30, 2012
(THOUSANDS)	AMORTIZED COST		TOTAL UNREALIZED GAINS (1)		TOTAL UNREALIZED LOSSES (1)		FAIR VALUE
Municipal bonds	$	4,477	$	2	$	9	$	4,470
(1)  Unrealized gains and losses are recorded to the restricted storm reserve.

Cleco Power recognized less than $0.1 million of unrealized mark-to-market losses in the restricted storm reserve for both the three and nine months ended September 30, 2012. The following table summarizes the securities that were in an unrealized loss position at September 30, 2012, but for which no other-than-temporary impairment was recognized:

			LESS THAN 12 MONTHS		12 MONTHS OR LONGER
(THOUSANDS)	AGGREGATE UNREALIZED LOSS		AGGREGATE RELATED FAIR VALUE		AGGREGATE UNREALIZED LOSS		AGGREGATE RELATED FAIR VALUE
Municipal bonds	$	9	$	3,381	$	—	$	—

At September 30, 2012, the fair value of Cleco Power's available-for-sale securities by contractual maturity was:

(THOUSANDS)	AT SEPT. 30, 2012
One year or less	$	1,022
Over one year through five years	3,448
Total fair value	$	4,470

There were no realized gains or losses on Cleco Power's available-for-sale securities during the three and nine months ended September 30, 2012 and 2011. Realized gains and losses will be determined on a specific identification basis.

Interest Rate Derivatives

Forward Starting Interest Rate Swap

On November 14, 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 a $50.0 million fixed-rate forecasted debt issuance. The forward starting interest rate swap has 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 is earlier. The forward starting interest rate swap meets the criteria of a cash flow hedge under the authoritative guidance as it relates to derivatives and hedging and is carried on the balance sheet at its fair value. The fair market value of the forward starting interest rate swap is the

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difference between the present value of the fixed payments to be paid by Cleco Power and the present value of the three-month LIBOR payments to be received by Cleco Power. Since future LIBOR rates are not available for each month until termination, quoted LIBOR rates from an active exchange for observable time periods were used to create a forward LIBOR curve for all months until termination. Because of the inputs and common techniques used to calculate fair value, the swap valuation was considered Level 2. Cleco Power recognized $0.8 million unrealized mark-to-market gains and $0.7 million unrealized mark-to-market losses in other comprehensive income for the three and nine months ended September 30, 2012, respectively. The fair market value of $4.1 million and $3.3 million for the forward starting interest rate swap was recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets as an interest rate risk

management liability as of September 30, 2012 and December 31, 2011, respectively. There was no impact to earnings due to ineffectiveness for the three and nine months ended September 30, 2012.

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 SEPT. 30, 2012		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2011		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Institutional money market funds	$	74,712	$	—	$	74,712	$	—	$	118,951	$	—	$	118,951	$	—
Municipal bonds	$	4,470	$	—	$	4,470	$	—	$	—	$	—	$	—	$	—
Total assets	$	79,182	$	—	$	79,182	$	—	$	118,951	$	—	$	118,951	$	—
Liability Description
Energy market derivatives	$	—	$	—	$	—	$	—	$	5,336	$	—	$	5,336	$	—
Interest rate derivatives	4,063		—		4,063		—		3,330		—		3,330		—
Long-term debt	1,553,694		—		1,553,694		—		1,542,867		—		1,542,867		—
Total liabilities	$	1,557,757	$	—	$	1,557,757	$	—	$	1,551,533	$	—	$	1,551,533	$	—

Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2012		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2011		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Institutional money market funds	$	61,115	$	—	$	61,115	$	—	$	99,955	$	—	$	99,955	$	—
Municipal bonds	$	4,470	$	—	$	4,470	$	—	$	—	$	—	$	—	$	—
Total assets	$	65,585	$	—	$	65,585	$	—	$	99,955	$	—	$	99,955	$	—
Liability Description
Energy market derivatives	$	—	$	—	$	—	$	—	$	5,336	$	—	$	5,336	$	—
Interest rate derivatives	4,063		—		4,063		—		3,330		—		3,330		—
Long-term debt	1,553,694		—		1,553,694		—		1,532,867		—		1,532,867		—
Total liabilities	$	1,557,757	$	—	$	1,557,757	$	—	$	1,541,533	$	—	$	1,541,533	$	—

The derivative assets and liabilities are classified as either current or non-current depending on when the positions close. All energy market derivative current assets and current liabilities are reported as a net current energy risk management asset or liability. All energy market derivative non-current assets and non-current liabilities are reported net in other deferred charges or other deferred credits. Net presentation is appropriate due to the right of offset included in the master netting agreements. On the balance sheet, the net current and net non-current derivative positions are netted with the applicable margin deposits.

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 in the amounts of $58.5 million, $3.4 million, and $12.8 million, respectively, at September 30, 2012. 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 and were $45.0 million, $3.4 million, and $12.7 million, respectively, as of September 30, 2012.

The municipal bonds were reported on Cleco and Cleco Power's Condensed Consolidated Balance Sheets in restricted investments in the amount of $4.5 million at September 30,

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2012.

The forward starting interest rate swap was reported on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets as a current liability in the line item interest rate risk management liability as of September 30, 2012.

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 for assets and liabilities are determined by obtaining the closing price from published indices in active markets for instruments that are similar to Cleco’s assets and liabilities. The fair value obtained is then discounted to the current period using a U.S. Treasury published interest rate as a proxy for a risk-free rate of return. For some options, Cleco uses the Black-Scholes model using observable and available inputs to calculate the fair value, consistent with the income approach. These techniques have been applied consistently from fiscal period to fiscal period. Level 3 fair values allow for situations in which there is little, if any, market activity for the asset or liability at the measurement date. Cleco had no Level 3 assets or liabilities at September 30, 2012 or December 31, 2011.

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.

Level 2 of energy market derivative assets and liabilities consists of two classes. The first class contains natural gas swaps which fluctuate in value as the underlying natural gas futures fair value changes, and as market interest rates change. Cleco records the mark-to-market value of the natural gas swaps at the net present value. The second class consists of natural gas options. The fair value of natural gas options fluctuates with the volatility in the fair value of natural gas, the number of days until the options expire, the underlying natural gas futures price fluctuations, and market interest rates. Cleco records the mark-to-market value of the natural gas options at the net present value. Both of these energy market derivative classes also contain counterparty execution risk because the transactions are entered into with a direct counterparty and are not traded through an exchange.

The Level 2 institutional money market funds asset consists of a single class. In order to capture interest income and minimize risk, cash is invested in money market funds that invest primarily in short-term securities issued by the U.S. Treasury 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 Level 2 municipal bonds consisted of a single class. In order to maximize income and to meet the requirements established by the LPSC for the restricted reserve fund, restricted cash and cash equivalents were invested in short-term, fixed-income, debt instruments in order to maintain safety and liquidity. The risks associated with this class are

counterparty risk of the fund manager and risk of price volatility associated with the municipal bonds. Quarterly, Cleco receives reports from the trustee for the investment manager which provides the fair value measurement. Cleco performs an evaluation of those reports to verify the fair value of the securities.

The Level 2 interest rate derivative was one forward starting interest rate swap liability that consisted of a single class that only contains one instrument. The risks are changes in the three-month LIBOR rate and counterparty risk. This instrument is with a direct counterparty and not traded through an exchange.

The Level 2 long-term debt liability consists of a single class. In order to fund capital requirements, Cleco issues long-term, fixed rate debt with various tenors. The fair value of this class fluctuates as the market interest rates for fixed rate debt with similar tenors and credit ratings changes. 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.

Cleco has a policy which states that transfers between Levels 1, 2, and 3 are recognized at the end of a reporting period. During the nine months ended September 30, 2012, and the year ended December 31, 2011, Cleco did not experience any transfers between levels.

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.

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 as of September 30, 2012 and December 31, 2011.

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
	LIABILITY DERIVATIVES
(THOUSANDS) FAIR VALUE	BALANCE SHEET  LINE ITEM	AT SEPT. 30, 2012		AT DEC. 31, 2011
Commodity contracts
Fuel cost hedges:
Current	Energy risk management liability, net	$	—	$	(5,336	)
Total		$	—	$	(5,336	)

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 and nine months ended September 30, 2012 and 2011.

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CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

	FOR THE THREE MONTHS ENDED SEPT. 30,								FOR THE NINE MONTHS ENDED SEPT. 30,
		2012			2011				2012			2011
(THOUSANDS)	LOSS IN  INCOME OF DERIVATIVES  LINE ITEM	AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			LOSS IN  INCOME OF DERIVATIVES  LINE ITEM	AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES
Commodity contracts
Fuel cost hedges(1)	Fuel used for electric generation	$	(595	)	$	(5,678	)	Fuel used for electric generation	$	(8,210	)	$	(14,675	)
Total		$	(595	)	$	(5,678	)		$	(8,210	)	$	(14,675	)
(1)In accordance with the authoritative guidance for regulated operations, no unrealized gains or losses and $0.1 million of deferred losses associated with fuel cost hedges are reported in Accumulated Deferred Fuel on the balance sheet as of September 30, 2012, compared to $5.3 million of unrealized losses and $1.2 million of deferred losses associated with fuel cost hedges as of December 31, 2011. As gains and losses are realized in future periods, they will be recorded as Fuel Used for Electric Generation on the income statement.

At September 30, 2012, Cleco Power had no open positions hedged for natural gas fuel costs. At December 31, 2011, Cleco Power had 2.2 million MMBtus hedged or approximately 3% of gas requirements for a two-year period.

The following tables present the effect of derivatives

designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2012 and 2011.

						FOR THE THREE MONTHS ENDED SEPT. 30,
	2012					2011
(THOUSANDS)	AMOUNT OF GAIN RECOGNIZED IN OCI		AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)			AMOUNT OF LOSS RECOGNIZED IN OCI			AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)
Interest rate derivatives	$	802	$	17	*	$	(29,962	)	$	89	*
* The gain (loss) reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.

							FOR THE NINE MONTHS ENDED SEPT. 30,
	2012						2011
(THOUSANDS)	AMOUNT OF LOSS  RECOGNIZED IN OCI			AMOUNT OF LOSS RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)			AMOUNT OF LOSS RECOGNIZED IN OCI			AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)
Interest rate derivatives(1)	$	(733	)	$	(39	)*	$	(29,962	)	$	267	*
* The (loss) gain reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.
(1) During the nine months ended September 30, 2012, Cleco recorded $2.6 million of ineffectiveness related to the interest rate derivatives as a regulatory asset.

At September 30, 2012, Cleco Power expected $0.4 million of the effective portion of deferred net losses related to interest rate derivatives to be reclassed from accumulated OCI to an increase in interest charges over the next 12 months.

Note 5 — Debt

Short-term Debt

At September 30, 2012 and December 31, 2011, Cleco and Cleco Power had no short-term debt outstanding.

Long-term Debt

At September 30, 2012, Cleco and Cleco Power's long-term debt outstanding was $1.33 billion, of which $90.9 million was due within one year. The long-term debt due within one year at September 30, 2012, represents $75.0 million in senior notes due May 1, 2013, $14.0 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $1.9 million of capital lease payments. For Cleco, long-term debt decreased$33.2 million from December 31, 2011, primarily due to Cleco Power redeeming $50.1 million of DeSoto Parish pollution control bonds in May 2012 and $11.2 million of Rapides Parish pollution control bonds in January 2012. Also contributing to the decrease was a $10.0 million reduction in Cleco Corporation's credit facility draws, and $13.1 million of scheduled Cleco Katrina/Rita storm recovery bond principal

payments made in March and September 2012. These decreases were partially offset by Cleco Power’s issuance of $50.0 million of senior notes in May 2012, $0.5 million of capital lease payments and debt premium amortizations of $0.7 million.

On January 25, 2012, Cleco Power redeemed at par $11.2 million of 5.875% Rapides Parish pollution control bonds due September 2029. As part of the redemption, Cleco Power paid $0.3 million of accrued interest on the redeemed notes.

On May 8, 2012, Cleco Power issued $50.0 million senior unsecured private placement notes at an interest rate of 4.33%.  The maturity date of the notes is May 15, 2027.  The proceeds were used primarily for the early redemption of $50.1 million of 5.875% DeSoto Parish pollution control bonds.

On May 11, 2012, Cleco Power redeemed at par all $50.1 million of 5.875% DeSoto Parish pollution control bonds due September 2029. As part of the redemption, Cleco Power paid $0.6 million of accrued interest on the redeemed notes.

Credit Facilities

At September 30, 2012, Cleco Corporation and Cleco Power had no borrowings outstanding under their respective existing credit facilities.

32

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

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 10 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. During the first nine months of 2012, Cleco made no discretionary or required contributions to the pension plan and does not expect to make required or discretionary contributions to the pension plan for the remainder of the year. During 2011, Cleco made $60.0 million in discretionary contributions to the pension plan, with $40.1 million designated for the 2010 plan year and the remaining $19.9 million designated for the 2011 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 are eligible to receive medical, dental, vision, and life insurance benefits (other benefits). Cleco recognizes the expected cost of these other benefits during the periods in which the benefits are earned.

The components of net periodic pension and other benefit cost for the three and nine months ended September 30, 2012 and 2011, are as follows:

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012		2011
Components of periodic benefit cost:
Service cost	$	2,078		$	2,097		$	303	$	390
Interest cost	4,563			4,407			334		443
Expected return on plan assets	(5,201		)	(6,161		)	—		—
Amortizations:
Transition obligation	—			—			5		5
Prior period service cost	(18		)	(18		)	—		(51		)
Net loss	2,087			1,389			112		246
Net periodic benefit cost	$	3,509		$	1,714		$	754	$	1,033

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012		2011
Components of periodic benefit cost:
Service cost	$	6,234		$	6,292		$	1,096	$	1,149
Interest cost	13,690			13,222			1,287		1,364
Expected return on plan assets	(15,604		)	(18,484		)	—		—
Amortizations:
Transition obligation	—			—			15		15
Prior period service cost	(53		)	(54		)	—		(154		)
Net loss	6,259			4,167			512		758
Net periodic benefit cost	$	10,526		$	5,143		$	2,910	$	3,132

Since Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred, with a like amount of assets, to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three and nine months ended September 30, 2012, was $0.5 million and $1.6 million, respectively. Amounts for the same periods in 2011 were also $0.5 million and $1.6 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 was $3.1 million at September 30, 2012. The amount at December 31, 2011, was also $3.1 million. The current portion of the other benefits liability for Cleco Power was $2.9 million at September 30, 2012. The amount at December 31, 2011, was also $2.9 million. The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2012, was $0.7 million and $2.5 million, respectively. Amounts for the same periods in 2011 were $0.9 million and $2.7 million, respectively.

In March 2010, the President signed the PPACA, a comprehensive health care law, which was upheld by the U.S. Supreme Court on June 28, 2012. While all provisions of the PPACA are not effective immediately, the provisions could increase the Registrants’ retiree medical unfunded liability and related expenses before the effective date. Management will continue to monitor this law and its possible impact on the Registrants.

SERP

Certain Cleco executive officers are covered by the SERP. The 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 and the average of the three highest 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 the SERP participants. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ life insurance benefits, as well as future SERP payments. However, since SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco 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 the SERP were made during the three and nine months ended September 30, 2012 or 2011. Cleco Power is considered the plan sponsor, and Support Group is considered the plan administrator.

33

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
Components of periodic benefit cost:
Service cost	$	372	$	392	$	1,115	$	1,175
Interest cost	632		526		1,895		1,578
Amortizations:
Prior period service cost	13		13		40		40
Net loss	441		234		1,324		705
Net periodic benefit cost	$	1,458	$	1,165	$	4,374	$	3,498

The SERP liabilities are reported on the individual subsidiaries’ financial statements. At September 30, 2012 and December 31, 2011, the current portion of the SERP liability for Cleco was $2.5 million and $2.2 million, respectively. The current portion of the SERP liability for Cleco Power was $0.8 million at September 30, 2012. The amount at December 31, 2011, was also $0.8 million. The expense related to the SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income was $0.4 million and $1.1 million for the three and nine months ended September 30, 2012, respectively, compared to $0.3 million and $0.9 million for the same periods in 2011.

401(k) Plan

Most employees are eligible to participate in the 401(k) Plan. Under the 401(k) Plan, Cleco makes matching contributions and funds dividend reinvestments with cash. Cleco’s 401(k) Plan expense for the three and nine monthsended September 30, 2012 and 2011 is as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
401(k) Plan expense	$	963	$	945	$	3,303	$	2,998

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and nine months ended September 30, 2012, was $0.2 million and $0.8 million, respectively. Amounts for the same periods in 2011 were $0.2 million and $0.7 million, respectively.

Note 7 — Income Taxes

The following table summarizes the effective income tax rates for Cleco and Cleco Power for the three and nine month periods ended September 30, 2012 and 2011.

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
	2012		2011		2012		2011
Cleco	24.0	%	27.3	%	27.8	%	30.8	%
Cleco Power	25.5	%	37.0	%	31.0	%	34.1	%

Effective Tax Rates

For the three and nine months ended September 30, 2012 and 2011, the effective income tax rate for Cleco was different than the federal statutory rate due to permanent tax deductions, flow-through of tax benefits associated with AFUDC equity, tax benefits delivered from Cleco’s investment in the NMTC Fund, other credits, favorable settlements with taxing authorities, and state tax expense.

For the three and nine months ended September 30, 2012 and 2011, the effective income tax rate for Cleco Power was different than the federal statutory rate due to permanent tax

deductions, other credits, favorable settlements with taxing authorities, flow-through 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 September 30, 2012, Cleco had a deferred tax asset resulting from New Markets Tax Credit carryforwards of $75.2 million. If the New Markets Tax Credit 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 New Markets Tax Credit carryforwards will be realized; therefore, no valuation allowance has been recorded.

Net Operating Losses

Cleco Corporation filed its 2011 federal income tax return and generated a $477.7 million net operating loss carryforward. Of the $477.7 million net operating loss carryforward generated, $436.9 million is attributable to Cleco Power. The net operating loss carryforward was primarily related to a tax accounting method change for bonus depreciation associated with Madison Unit 3. On July 3, 2012, Cleco filed a Private Letter Ruling request with the IRS in order to determine the appropriateness and timing of taking this special depreciation deduction for Madison Unit 3.  The IRS is expected to take up to six months to consider the ruling request and issue a final ruling on the matter. Cleco and Cleco Power consider it more likely than not that these losses will be utilized to reduce future income taxes and both Cleco and Cleco Power expect to utilize the entire net operating loss carryforward within the next four years.

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 uncertain tax positions and related interest payable and interest expense, as reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets and Statements of Income, are shown in the following tables.

(THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
Interest payable
Cleco	$	2,166	$	13,843
Cleco Power	$	5,502	$	17,327

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 September 30, 2012 and December 31, 2011, are $6.0 million and $9.3 million, respectively.

	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012			2011
Interest charges
Cleco	$	(121	)	$	93		$	(8,477	)	$	2,954
Cleco Power	$	133		$	(420	)	$	(9,504	)	$	1,356

The interest charges reflect the amount of interest anticipated to be paid to 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

34

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

expected to be recoverable from Cleco Power's customers under existing rate orders at September 30, 2012 and December 31, 2011, are $3.3 million and $1.6 million, respectively.

The total liability for unrecognized tax benefits for Cleco at September 30, 2012 and December 31, 2011, is shown in the following table.

Cleco
(THOUSANDS)	LIABILITY FOR UNRECOGNIZED TAX BENEFITS
Balance at December 31, 2011	$	56,235
Additions for tax positions of current period	640
Reductions for tax positions of current period	—
Additions for tax positions of prior periods	—
Reduction for tax positions of prior periods	22,418
Reduction for settlement with tax authority	32,062
Reduction for lapse of statute of limitations	—
Balance at September 30, 2012	$	2,395

The total liability (asset) for unrecognized tax benefits for Cleco Power at September 30, 2012 and December 31, 2011, is shown in the following table.

Cleco Power
(THOUSANDS)	LIABILITY (ASSET) FOR UNRECOGNIZED TAX BENEFITS
Balance at December 31, 2011	$	52,558
Additions for tax positions of current period	640
Reductions for tax positions of current period	—
Additions for tax positions of prior periods	—
Reduction for tax positions of prior periods	21,327
Reduction for settlement with tax authority	32,062
Reduction for lapse of statute of limitations	—
Balance at September 30, 2012	$	(191	)

The federal income tax years that remain subject to examination by the IRS are 2001 through 2011. The Louisiana state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2001 through 2011. In December 2010, Cleco deposited $52.2 million with the IRS associated with the years under audit. In February 2011, Cleco deposited an additional $8.2 million with the IRS associated with the years currently under audit. Of the $60.4 million deposited, $43.5 million remains to either offset tax and interest liabilities for tax years subsequent to 2003 or to be refunded.

Cleco is currently under audit by the IRS for the years 2001 through 2009. Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of September 30, 2012, could decrease by a maximum of $0.6 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.

Note 8 — Disclosures about Segments

Cleco’s reportable segments are based on its method of internal reporting, which disaggregates business units by first-tier subsidiary. Cleco’s reportable segments are Cleco Power and Midstream. The reconciling items in the following tables consist of the holding company, a shared services subsidiary, two transmission interconnection facilities, and an investment subsidiary.

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 2012 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. These intercompany transactions relate primarily to joint and common administrative support services provided by Support Group.

35

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED SEPTEMBER 30,
2012 (THOUSANDS)	CLECO POWER			MIDSTREAM			RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	282,894		$	—		$	—		$	—		$	282,894
Tolling operations	—			13,890			—			(13,890		)	—
Other operations	14,905			1			502			—			15,408
Electric customer credits	(930		)	—			—			—			(930		)
Affiliate revenue	343			—			12,343			(12,686		)	—
Operating revenue, net	$	297,212		$	13,891		$	12,845		$	(26,576	)	$	297,372
Depreciation	$	33,199		$	1,499		$	233		$	—		$	34,931
Interest charges	$	21,962		$	(69	)	$	(124	)	$	197		$	21,966
Interest income	$	129		$	—		$	(194	)	$	197		$	132
Federal and state income tax expense (benefit)	$	19,740		$	2,489		$	(2,050	)	$	—		$	20,179
Segment profit	$	57,783		$	3,429		$	2,606		$	—		$	63,818
Additions to long-lived assets	$	65,073		$	799		$	503		$	—		$	66,375
Equity investment in investees	$	14,532		$	—		$	9		$	—		$	14,541
Total segment assets	$	3,840,131		$	221,503		$	194,996		$	(149,737	)	$	4,106,893

2011 (THOUSANDS)	CLECO POWER		MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	324,532	$	—	$	—		$	—		$	324,532
Tolling operations	—		9,133		—			—			9,133
Other operations	15,565		1		500			(2		)	16,064
Electric customer credits	1,852		—		—			—			1,852
Affiliate revenue	347		—		13,448			(13,795		)	$	—
Operating revenue, net	$	342,296	$	9,134	$	13,948		$	(13,797	)	$	351,581
Depreciation	$	29,539	$	1,457	$	241		$	—		$	31,237
Interest charges	$	25,306	$	752	$	(308	)	$	29		$	25,779
Interest income	$	276	$	5	$	199		$	29		$	509
Equity loss from investees, before tax	$	—	$	—	$	(1	)	$	—		$	(1	)
Federal and state income tax expense (benefit)	$	31,656	$	444	$	(7,363	)	$	—		$	24,737
Segment profit	$	53,833	$	5,946	$	6,063		$	—		$	65,842
Additions to long-lived assets	$	76,213	$	4,074	$	81		$	—		$	80,368
Equity investment in investees (1)	$	14,532	$	—	$	8		$	—		$	14,540
Total segment assets  (1)	$	3,726,471	$	233,891	$	201,074		$	(111,234	)	$	4,050,202
(1) Balances as of December 31, 2011

36

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

SEGMENT INFORMATION FOR THE NINE MONTHS ENDED SEPTEMBER 30,
2012 (THOUSANDS)	CLECO POWER		MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	720,776	$	—	$	—		$	—		$	720,776
Tolling operations	—		21,434		—			(21,434		)	—
Other operations	36,967		2		1,496			(1		)	38,464
Electric customer credits	1,025		—		—			—			1,025
Affiliate revenue	1,030		—		37,540			(38,570		)	—
Operating revenue	$	759,798	$	21,436	$	39,036		$	(60,005	)	$	760,265
Depreciation	$	93,847	$	4,491	$	689		$	1		$	99,028
Interest charges	$	61,253	$	244	$	1,320		$	388		$	63,205
Interest income	$	153	$	—	$	(379	)	$	389		$	163
Equity income from investees, before tax	$	—	$	—	$	1		$	—		$	1
Federal and state income tax expense (benefit)	$	54,748	$	7,278	$	(7,916	)	$	—		$	54,110
Segment profit	$	121,873	$	11,053	$	7,610		$	—		$	140,536
Additions to long-lived assets	$	159,836	$	6,811	$	1,371		$	—		$	168,018
Equity investment in investees	$	14,532	$	—	$	9		$	—		$	14,541
Total segment assets	$	3,840,131	$	221,503	$	194,996		$	(149,737	)	$	4,106,893

2011 (THOUSANDS)	CLECO POWER			MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	823,484		$	—	$	—		$	—		$	823,484
Tolling operations	—			16,137		—			—			16,137
Other operations	40,261			8		1,511			(5		)	41,775
Electric customer credits	(3,405		)	—		—			—			(3,405		)
Affiliate revenue	1,041			45		37,544			(38,428		)	202
Operating revenue	$	861,381		$	16,190	$	39,055		$	(38,433	)	$	878,193
Depreciation	$	86,650		$	4,370	$	728		$	1		$	91,749
Interest charges	$	74,029		$	1,963	$	1,891		$	128		$	78,011
Interest income	$	557		$	6	$	103		$	128		$	794
Equity income (loss) from investees, before tax	$	—		$	62,053	$	(2	)	$	—		$	62,051
Federal and state income tax expense (benefit)	$	61,935		$	21,296	$	(9,781	)	$	1		$	73,451
Segment profit (1)	$	119,557		$	39,274	$	6,374		$	—		$	165,205
Additions to long-lived assets	$	152,082		$	5,202	$	749		$	—		$	158,033
Equity investment in investees (2)	$	14,532		$	—	$	8		$	—		$	14,540
Total segment assets (2)	$	3,726,471		$	233,891	$	201,074		$	(111,234	)	$	4,050,202
(1) Reconciliation of segment profit to consolidated profit:	Segment profit								$	165,205
(2) Balances as of December 31, 2011	Unallocated items:
	Preferred dividends requirements								26
	Preferred stock redemption costs								112
	Net income applicable to common stock								$	165,067

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Note 9 — Electric Customer Credits

Beginning in 2010, the amount of Cleco Power’s yearly retail earnings is subject to the terms of an FRP established by the LPSC. The rates and the FRP became effective upon commencement of commercial operations at Madison Unit 3 on February 12, 2010. The 2010 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, 2011, Cleco Power filed its report for the 12 months endedJune 30, 2011, which indicated that $5.1 million was due to be returned to customers. On July 18, 2012, the LPSC approved the monitoring report for the 12 months ended June 30, 2011. Cleco Power issued refunds for this filing on customers' bills during the third quarter of 2012.

Cleco Power expects to file its monitoring report for the 12 months endedJune 30, 2012, by October 31, 2012, which will indicate $1.7 million is due to be returned to customers.

The accrual for estimated electric customer credits reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2012 and December 31, 2011, was $2.5 million and $7.3 million, respectively.

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.

Prior to April 30, 2011, Cleco Corporation also reported its investment in Cajun on the equity method of accounting. In conjunction with the disposition of Acadia Unit 2, APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH.

Consolidated VIEs

Acadia

In October 2009, Acadia and Entergy Louisiana announced that definitive agreements had been executed whereby Entergy Louisiana would acquire Acadia Unit 2.  On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 to Entergy Louisiana for $298.8 million. Following the disposition, Acadia no longer owns any materials and supply inventory, property, plant, and equipment, or land. Following the transaction, ongoing operations at Acadia are minimal, relating only to the previously established accounts receivable, accounts payable, and servicing indemnifications which Cleco assumed in the transaction. In conjunction with the transaction, APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH. For more information on the

Acadia Unit 2 transaction, see Note 13 — “Acadia Unit 2 Transaction.”

The following table contains summarized financial information for Cajun prior to the disposition of Acadia Unit 2.

(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2011*
Operating revenue		$	5,227
Operating expenses		5,914
Gain on sale of assets		71,422
Other income		929
Income before taxes		$	71,664
*The 2011 income statement includes only activity through the April 29, 2011, reconsolidation.

Prior to the reconsolidation, income tax expenses related to Cajun were recorded on APH’s financial statements. For the four months ended April 30, 2011, income tax expenses related to Cajun on APH’s financial statements were $24.0 million.

Equity Method VIEs

Equity investment in investees at September 30, 2012, primarily represented Cleco Power’s $14.5 million investment in Oxbow. Equity investments which are less than 100% owned by Cleco Innovations LLC represented less than $0.1 million of the total balance.

The following table presents the equity income (loss) from each investment accounted for using the equity method.  

	FOR THE THREE MONTHS ENDED SEPT. 30,					FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011			2012		2011
Cajun	$	—	$	—		$	—	$	62,053
Subsidiaries less than 100% owned by Cleco Innovations	—		(1		)	1		(2		)
Total equity (loss) income	$	—	$	(1	)	$	1	$	62,051

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 September 30, 2012, 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 SEPT. 30, 2012		AT DEC. 31, 2011
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 SEPT. 30, 2012		AT DEC. 31, 2011
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

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The following tables contain summarized financial information for Oxbow.

(THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
Current assets	$	1,753	$	1,711
Property, plant, and equipment, net	23,119		23,339
Other assets	4,247		4,128
Total assets	$	29,119	$	29,178
Current liabilities	$	24	$	40
Other liabilities	30		73
Partners’ capital	29,065		29,065
Total liabilities and partners’ capital	$	29,119	$	29,178

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
Operating revenue	$	450	$	382	$	1,125	$	880
Operating expenses	450		382		1,125		880
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.

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 potentially responsible parties (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 has identified Cleco as one of many companies sending PCB wastes for disposal to the site. The Devil’s Swamp Lake site has been proposed to be added to the National Priorities List (NPL) based on the release of PCBs to fisheries and wetlands located on the site. The EPA has yet to make a final determination on whether to add Devil’s Swamp Lake site to the NPL. The PRPs began discussing a potential proposal to the EPA in February 2008 and since that time, Cleco is unaware of any progress made in regard to the RI/FS negotiations. 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

On December 11, 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 is seeking various remedies provided under applicable statutes prohibiting racial discrimination in the workplace, and together, the plaintiffs seek monetary compensation exceeding $35.0 million. On July 29, 2010, the plaintiffs moved to add an additional current employee alleging that Cleco had discriminated on the basis of race. The additional plaintiff seeks compensation of no less than $2.5 million and became the 13th plaintiff. On April 13, 2011, Cleco entered into a settlement with one of the current employees which resulted in a dismissal of one of the 13 cases with prejudice. In September 2011, the Court ruled on Cleco’s summary judgment motions. The judge granted and denied the motions in part, with the end result that 11 out of 12 of the remaining plaintiffs have at least one claim remaining. The Court has severed the cases of the 11 remaining plaintiffs for further proceedings, and, if necessary, the trial. Additional depositions were completed in February 2012, and Cleco filed a summary judgment motion in each of the remaining 11 cases on March 8, 2012. Each of such motions was fully briefed and submitted for decision by May 11, 2012. None of these cases has been set for trial and likely will not be set until the Court rules on Cleco’s motions for summary judgment.

On July 31, 2012, nine of the eleven plaintiffs in the pending discrimination suits described above filed a new lawsuit in the same federal court in Shreveport alleging that Cleco and its Chief Executive Officer retaliated against them for pursuing their discrimination claims by directly writing them an offer of settlement that contained allegedly intimidating threats. The nine plaintiffs consist of six current employees and three former employees. The plaintiffs filed an amended complaint on August 29, 2012, stating that such settlement letters were delivered to legal counsel for each of the plaintiffs and not directly to the plaintiffs. On September 6, 2012, Cleco filed a motion to dismiss the lawsuit. The basis of such motion is Cleco's argument that statements made in an offer of settlement cannot constitute retaliation and give rise to damages pursuant to judicial policies favoring settlement. Otherwise Cleco argues that the amended complaint fails to state a cause of action upon which relief can be granted.

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.

City of Opelousas

On March 9, 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. Cleco Power currently operates in Opelousas pursuant to a franchise granted to Cleco Power by the City of Opelousas in 1986 and

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an operating and franchise agreement dated May 14, 1991, pursuant to which Cleco Power operates its own electric facilities and leases and operates electric facilities owned by the City of Opelousas. 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 addition, Cleco Power removed the purported class action lawsuit filed on behalf of Opelousas electric customers from the state court to the U.S. District Court for the Western District of Louisiana in April 2010, so that it could be properly addressed under the terms of the Class Action Fairness Act. On May 11, 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. Cleco Power has responded in the same manner as with the first class action lawsuit. In September 2010, the federal court remanded both cases to the state court in which they were originally filed for further proceedings. 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 November 2011, the Louisiana Supreme Court granted the appeals and remanded the case to the Third Circuit for further briefing, argument, and opinion. 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. On January 30, 2012, the class action plaintiffs filed their appeal of such LPSC decision to the 19th Judicial District Court for Baton Rouge Parish, State of Louisiana. On February 15, 2012, the Third Circuit ruled that the state court, and not the LPSC, has jurisdiction to hear the case. On March 15, 2012, Cleco Power appealed the Third Circuit’s ruling to the Louisiana Supreme Court asking that it overturn the Third Circuit decision and confirm the LPSC’s exclusive jurisdiction over this matter. The LPSC also appealed the Third Circuit’s ruling to the Louisiana Supreme Court in March 2012. On May 18, 2012, the Louisiana Supreme Court granted the writ application of Cleco Power and the LPSC and set the matter for further briefing on the merits of the jurisdiction question raised in the writ application. Such briefing was completed during the third quarter of 2012 and the Louisiana Supreme Court heard oral arguments on September 7, 2012. A decision from the Louisiana Supreme Court is expected during the fourth quarter of 2012. 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.

LPSC Audits

Fuel Audit

The cost of fuel used for electric generation and the cost of power purchased for utility customers are recovered through an LPSC-established fuel adjustment clause that enables Cleco Power to pass on to its customers substantially all such charges. The LPSC Fuel Adjustment Clause General Order issued November 6, 1997, in Docket No. U-21497 provides that an audit of fuel adjustment clause filings will be performed not less than every other year. In March 2009, the LPSC initiated an audit of fuel adjustment clause filings for the years 2003 through 2008. The total amount of fuel expenses included in the audit was approximately $3.26 billion. In February 2012, the LPSC Staff’s consultant issued a preliminary audit report recommending a cost disallowance of approximately $0.4 million plus interest for these filing years. There was no opposition from intervenors to the recommendations of the LPSC Staff’s consultant and the report was approved by the LPSC on July 18, 2012. Cleco Power made refunds of $0.4 million plus interest to customers during the September 2012 billing cycle. Cleco Power has fuel adjustment clause filings for the years 2009 through 2011 that remain subject to audit.

Environmental Audit

In July 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides for an environmental adjustment clause to recover certain costs of environmental compliance as an adder to customers’ bills. The costs eligible for recovery are prudently incurred air emissions credits associated with complying with federal, state, and local air emission regulations that apply to the generation of electricity reduced by the sale of such allowances. Also eligible for recovery are variable emission mitigation costs, which are the cost of reagents such as ammonia and limestone that are used to reduce air emissions. In November 2011, the LPSC initiated an audit of the costs for the period October 2009 through October 2010. The total amount of environmental expenses included in the audit was approximately $11.3 million. In April 2012, the LPSC Staff’s consultant issued a preliminary audit report recommending no cost disallowance for the review period. There was no opposition from intervenors to the recommendations of the LPSC Staff’s consultant and the report was approved by the LPSC on July 18, 2012. Cleco Power has environmental adjustment clause filings for the years 2010 through 2012 that remain subject to audit.

Other

Cleco is involved in various litigation matters, including regulatory, environmental, and administrative proceedings before various courts, regulatory commissions, arbitrators, and governmental agencies regarding matters arising in the ordinary course of business. The liability Cleco may ultimately incur with respect to any one of these matters in the event of a negative outcome may be in excess of amounts currently accrued. Management regularly analyzes current information and, as of September 30, 2012, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters is approximately $2.5 million.

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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 also have 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 September 30, 2012, 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 SEPT. 30, 2012
(THOUSANDS)	FACE AMOUNT		REDUCTIONS		NET AMOUNT
Cleco Corporation
Guarantee issued to Entergy Mississippi on behalf of Attala	$	500	$	—	$	500
Cleco Power
Obligations under standby letter of credit issued to the Louisiana Department of Labor	3,725		—		3,725
Total	$	4,225	$	—	$	4,225

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 through the life of the agreement.

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.

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 September 30, 2012, 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 February 2010, Cleco Power acquired Acadia Unit 1 and half of Acadia Power Station’s related common facilities. Acadia provided limited guarantees and indemnifications to Cleco Power under the Master Reorganization and Redemption Agreement. The maximum amount of the potential payment to Cleco Power for indemnifications is $30.0 million, except for the indemnifications relating to the fundamental organizational structure of Acadia against which there is no maximum amount. Cleco Corporation is obligated to pay a maximum of $10.0 million if Acadia is unable to pay claims to Cleco Power pursuant to the guarantee. Acadia recorded an indemnification liability of $13.5 million which represents the fair value of these indemnifications.

Acadia and APH will reduce the indemnification liabilities either 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 approximately three years. After the three-year period, a residual value of less than $0.1 million will remain. At September 30, 2012, Acadia had an indemnification liability of approximately $0.4 million remaining, which represents the risk of payment, as a contingent sale obligation recorded on Cleco’s Condensed Consolidated Balance Sheet. APH recognized no income for the three and nine months ended September 30, 2012, and no income for the three months ended September 30, 2011, and $0.5 million for the nine months ended September 30, 2011, respectively, primarily due to the contractual expiration of the underlying indemnifications. Acadia recognized no income for the three months ended September 30, 2012, and income of $7.2 million for the nine months ended September 30, 2012, primarily due to the contractual expiration of the underlying indemnifications. During the three and nine months ended September 30, 2011, Acadia recognized income of $1.0 million and $1.1 million, respectively, primarily due to the contractual expiration of the underlying indemnifications.

On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 and Acadia Power Station’s remaining common facilities to Entergy Louisiana. Acadia provided limited guarantees and indemnifications to Entergy Louisiana and recorded an indemnification liability of $21.8 million, which represents the fair value of these indemnifications. In conjunction with the disposition of Acadia Unit 2, APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH.

Acadia and APH will reduce the indemnification liabilities either 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 September 30, 2012, Acadia had an indemnification liability of $10.0 million remaining, which represents the risk of payment, as a contingent sale obligation recorded on Cleco’s Condensed Consolidated Balance Sheet. Acadia recognized no income for the three months ended September 30, 2012, and $11.8 million for the nine months ended September 30, 2012, primarily due to the contractual expiration of the underlying

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indemnifications. 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 by Acadia, 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 lignite miner’s loan and lease principal obligations when due, if the lignite miner does not have sufficient funds or credit to pay. Any amounts paid on behalf of the miner would be credited by the lignite miner against the next invoice for lignite delivered. At September 30, 2012, 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 $72.5 million; however, the Amended Lignite Mining Agreement does not contain a cap. The projection is based on the forecasted loan and lease obligations to be incurred by DHLC, primarily for purchases of equipment. Cleco Power has the right to dispute the incurrence of loan and lease obligations through the review of the mining plan before the incurrence of such loan and lease obligations. The Amended Lignite Mining Agreement does not terminate pursuant to its terms until 2026 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 termination dates of the off-balance sheet commitments and on-balance sheet guarantees discussed above.

							AT SEPT. 30, 2012
			AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
(THOUSANDS)	NET AMOUNT COMMITTED		LESS THAN ONE YEAR		1-3 YEARS		3-5 YEARS		MORE THAN 5 YEARS
Off-balance sheet commitments	$	4,225	$	3,725	$	—	$	—	$	500
On-balance sheet guarantees	14,356		—		10,350		—		4,006
Total	$	18,581	$	3,725	$	10,350	$	—	$	4,506

Other Commitments

New Markets Tax Credits

In 2008, Cleco Corporation and US Bancorp Community Development (USBCDC) formed the NMTC Fund. Cleco has a 99.9% membership interest in the NMTC Fund and USBCDC has a 0.1% interest in the NMTC Fund. The purpose of the NMTC Fund is to invest in projects located in qualified active low-income communities that are underserved by typical debt capital markets. These investments are designed to generate New Markets Tax Credits 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 American Recovery and Reinvestment Tax Act of 2009. The tax benefits received from the NMTC Fund reduce the federal income tax obligations of Cleco Corporation. In total, Cleco Corporation will contribute $285.5 million of equity contributions to the NMTC Fund and will receive at least $303.8 million in the form of tax credits, tax losses, capital gains/losses, earnings and cash over the life of the investment, which ends in 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
Three months ending Dec. 31, 2012	$	12,786
Years ending Dec. 31,
2013	50,822
2014	39,059
2015	12,975
2016	11,890
2017	3,292
Total	$	130,824

Of the $130.8 million, $51.6 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 September 30, 2012, was $104.7 million. The amount of tax benefits delivered but not utilized as of September 30, 2012, was $86.5 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

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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:	$	130,824
Less:  unamortized discount	12,291
Total	$	118,533

The gross investment amortization expense will be recognized over a ten-year period, with five years remaining under the new amendment, using the cost method in accordance with the authoritative guidance for investments. The grants received under Section 1603 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.

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. After assessing the current operating performance, liquidity, and credit ratings of Cleco Corporation, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. If Cleco Corporation’s credit ratings were to be downgraded by Moody’s and Standard & Poor’s, 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 supplies the majority of its customers’ electric power requirements from its own generation facilities. In addition to power obtained from power purchase agreements, Cleco Power purchases power from other utilities and marketers to supplement its generation at times of relatively high demand or when the purchase price of power is less than its own cost of generation. Due to its location on the transmission grid, Cleco Power relies on two main suppliers of electric transmission when accessing external power markets. At times, constraints limit the amount of purchased power these transmission providers can deliver into Cleco Power’s service territory.

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. After assessing the current operating performance, liquidity, and credit ratings of Cleco Power, management believes that Cleco Power will have

access to the capital markets at prevailing market rates for companies with comparable credit ratings. 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 and Standard & Poor’s, 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 Standard & Poor’s, Cleco Power would be required to pay additional collateral for derivatives.

Note 12 — Affiliate Transactions

At September 30, 2012, Cleco Corporation had no affiliate balances that were payable to or due from its non-consolidated affiliates.

Cleco Power has affiliate balances that are payable to or due from its affiliates. At September 30, 2012, the payable to Support Group was $5.7 million, the payable to Cleco Corporation was $0.8 million, the payable to Evangeline was $3.5 million, and the payable to other affiliates was less than $0.1 million. Also, at September 30, 2012, the receivable from Support Group was $2.0 million, the receivable from Cleco Corporation was $1.3 million, and the receivable from other affiliates was less than $0.1 million.

Note 13 — Acadia Unit 2 Transaction

On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 and Acadia Power Station’s remaining common facilities to Entergy Louisiana. The significant terms of the transaction were:

• Entergy Louisiana acquired Acadia Unit 2 for $298.8 million,

• In exchange for $10.9 million, APH indemnified the third-party owners of Cajun and their affiliates against 50% of Acadia’s liabilities and other obligations related to the Acadia Unit 2 transaction,

• APH recognized a gain of $62.0 million, which included $26.2 million of equity income that represents the 2007 investment impairment charge of $45.9 million, partially offset by $19.7 million of capitalized interest during the construction of Acadia,

• APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH, and

• Cleco Power operates Acadia Unit 2 on behalf of Entergy Louisiana.

Following the transaction, ongoing operations at Acadia are minimal, relating only to the previously established accounts receivable, accounts payable, and servicing of indemnities. Therefore, Acadia does not meet the definition of a business.

Note 14 — Storm Restoration

On August 28, 2012, Hurricane Isaac made landfall in south Louisiana as a Category 1 hurricane, causing power outages to approximately 95,000, or 34%, of Cleco Power’s electric customers and affecting Cleco Power’s entire service territory. By September 2, 2012, power was restored to 100% of customers who could receive power.

The current estimate of the cost of restoration for Hurricane Isaac is approximately $21.4 million. The damage

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to equipment from the storm required replacement, as well as repair of existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 61.8% of the restoration costs recorded at September 30, 2012, or approximately $13.2 million. The remaining cost was offset against Cleco Power’s existing storm damage reserve.

Note 15 — Subsequent Event

On October 30, 2012, Cleco Power announced Evangeline as the winning bidder in Cleco Power's 2012 Long-Term RFP, subject to further due diligence, the completion of definitive agreements, and regulatory approvals from the LPSC and FERC. The transaction is a transfer of ownership and control of Coughlin Power Station from Evangeline to Cleco Power.  The transaction is expected to be closed in the third quarter of 2013, after the completion of regulatory reviews.

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

The following discussion and analysis should be read in combination with the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011, and Cleco and Cleco Power’s Condensed Consolidated Financial Statements contained in this Combined Quarterly Report on Form 10-Q. The information included therein is essential to understanding the following discussion and analysis. Below is information concerning the consolidated results of operations of Cleco for the three and nine months ended September 30, 2012 and September 30, 2011.

RESULTS OF OPERATIONS

Overview

Cleco is a regional energy company that conducts substantially all of its business operations through its two primary subsidiaries:

• Cleco Power, a regulated electric utility company, which owns 9 generating units with a total nameplate capacity of 2,524 MW and serves approximately 281,000 customers in Louisiana through its retail business and 10 communities across Louisiana and Mississippi through wholesale power contracts and

• Midstream, a wholesale energy business, which owns Evangeline (which operates Coughlin).

Cleco Power

Many factors affect Cleco Power’s primary business of selling electricity. These factors include the presence of a stable regulatory environment, which can impact cost recovery and return on equity, as well as the recovery of costs related to growing energy demand and rising fuel prices; the ability to increase energy sales while containing costs; and the ability to meet increasingly stringent regulatory and environmental standards. Key initiatives that Cleco Power is currently working on include the Acadiana Load Pocket project, the AMI project and long-term power supply options beyond 2012. These initiatives are discussed below.

Acadiana Load Pocket Project

In September 2008, Cleco Power entered into an agreement with two other utilities to upgrade and expand interconnected transmission systems in south central Louisiana in an area known as the Acadiana Load Pocket. The project received LPSC and SPP approval in February 2009. Cleco Power’s estimated cost for its portion of the project is $125.0 million, including AFUDC. As of September 30, 2012, Cleco Power had spent $119.6 million on the project. A return on and recovery of the costs associated with the completed portions of the Acadiana Load Pocket project are included in base

revenue. The project was substantially completed by the end of June 2012. Remaining portions of the project are expected to be complete by December 2012. For information on the impact the Acadiana Load Pocket project is expected to have on base revenue, see “— Comparison of the Three Months Ended September 30, 2012 and 2011 — Cleco Power — Base.”

AMI Project

In May 2010, Cleco Power accepted the terms of a $20.0 million grant from the DOE under the DOE’s small-grant process to implement advanced metering technology for all of Cleco Power’s retail customers. Cleco Power estimates the project will cost $73.0 million, with the DOE grant providing $20.0 million toward the project and Cleco Power providing the remaining $53.0 million. The grant program is a part of the American Recovery and Reinvestment Act of 2009, an economic stimulus package passed by Congress in February 2009. Advanced metering technology includes the installation of electric meters that enable two-way communication capabilities between a home or business and a utility company. At September 30, 2012, Cleco Power had incurred $45.4 million in project costs, of which $20.0 million has been submitted to the DOE for reimbursement. As of September 30, 2012, Cleco Power had received $18.5 million in payments from the DOE. The project is expected to be completed in the third quarter of 2013. For more information on the AMI Project, see "— Financial Condition — Regulatory and Other Matters — AMI Project."

Power Supply Options

Cleco Power is evaluating a range of long-term power supply options beyond 2012. Cleco Power is continuing to update its IRP to look at future sources of supply to meet its capacity and energy requirements and to comply with new environmental standards. In August 2011, Cleco Power issued an RFP for resources to enhance reliability for January through April 2012 and selected and negotiated two agreements from the RFP, a power purchase agreement with NRG Power Marketing LLC and a tolling agreement with Evangeline. Both agreements began on January 1, 2012 and ended on April 30, 2012. In October 2011, a second RFP, seeking up to approximately 750 MW of capacity and energy, for a three- or five-year period was issued for supply starting May 1, 2012. Cleco Power selected Evangeline’s proposal for a 730-MW product beginning May 1, 2012, and ending April 30, 2015. The definitive agreement between Evangeline and Cleco Power was executed in January 2012 and approved by the LPSC in March 2012 and FERC in April 2012. In May 2012, Cleco Power issued a draft RFP seeking long-term resources beyond April 2015. The final RFP was issued in July 2012 and proposals were received

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from potential suppliers in August 2012. On October 30, 2012, Cleco Power announced Evangeline as the winning bidder in Cleco Power's 2012 Long-Term RFP. For more information on Cleco Power's RFPs, see “— Financial Condition — Regulatory and Other Matters — Generation RFP” and Item 1, "Notes to the Unaudited Condensed Consolidated Financial Statements — Note 15 — Subsequent Event."

Cleco Midstream

Evangeline

In March 2010, Evangeline restructured its tolling agreement with JPMVEC and shortened the expiration of the prior long-term agreement from 2020 to December 31, 2011 (with a JPMVEC option to extend one year). JPMVEC did not exercise the option to extend the tolling agreement and as a result, Coughlin’s capacity and energy became available to Midstream beginning January 1, 2012. Evangeline was one of the successful bidders in Cleco Power’s RFP for short-term 2012 resources beginning January 1, 2012, and began providing 250 MW of capacity and energy to Cleco Power under a tolling agreement through April 30, 2012. In addition to Cleco Power’s RFP referenced above, in December 2011, Evangeline was also notified that Cleco Power selected its proposal to fulfill Cleco Power’s capacity and energy needs as defined in the Cleco Power RFP for contractual resources beginning in 2012. The proposal was for a 730-MW product beginning May 1, 2012 and ending April 30, 2015. The definitive agreement between Evangeline and Cleco Power was executed in January 2012 and was approved by the LPSC in March 2012 and FERC in April 2012. Midstream has been marketing Coughlin’s capacity for periods beginning after April 30, 2015, and has been evaluating various options to optimize Coughlin’s value. On October 30, 2012, Cleco Power announced that Evangeline was the winning bidder in Cleco Power's 2012 Long-Term RFP. For more information, see “— Financial Condition — Regulatory and Other Matters — Generation RFP” and Item 1, "Notes to the Unaudited Condensed Consolidated Financial Statements — Note 15 — Subsequent Event."

Comparison of the Three Months Ended September 30, 2012 and 2011

Cleco Consolidated
	FOR THE THREE MONTHS ENDED SEPT. 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2012		2011			VARIANCE			CHANGE
Operating revenue, net	$	297,372	$	351,581		$	(54,209	)	(15.4	)%
Operating expenses	194,025		236,081			42,056			17.8	%
Operating income	$	103,347	$	115,500		$	(12,153	)	(10.5	)%
Allowance for other funds used during construction	$	1,882	$	902		$	980		108.6	%
Other expense	$	1,232	$	2,680		$	1,448		54.0	%
Interest charges	$	21,966	$	25,779		$	3,813		14.8	%
Federal and state income taxes	$	20,179	$	24,737		$	4,558		18.4	%
Net income applicable to common stock	$	63,818	$	65,842		$	(2,024	)	(3.1	)%

Consolidated net income applicable to common stock decreased $2.0 million, or 3.1%, in the third quarter of 2012 compared to the third quarter of 2011 primarily due to lower Midstream and corporate earnings. Partially offsetting this decrease was higher Cleco Power earnings.

Operating revenue, net decreased $54.2 million, or 15.4%, in the third quarter of 2012 compared to the third quarter of 2011 largely as a result of lower fuel cost recovery revenue at Cleco Power.

Operating expenses decreased $42.1 million, or 17.8%, in the third quarter of 2012 compared to the third quarter of 2011 primarily due to lower per unit costs and volumes of fuel used for electric generation.

Allowance for funds used during construction increased $1.0 million, or 108.6%, in the third quarter of 2012 compared to the third quarter of 2011 primarily due to higher AFUDC related to the AMI Project and miscellaneous transmission projects, partially offset by lower amounts from the Acadiana Load Pocket Project and the absence of amounts related to the completion of Teche Unit 4.

Other expense decreased $1.4 million, or 54.0%, in the third quarter of 2012 compared to the third quarter of 2011 largely as a result of an increase in the cash surrender value of life insurance policies at Cleco Corporation.

Interest charges decreased $3.8 million, or 14.8%, during the third quarter of 2012 compared to the third quarter of 2011 primarily due to lower interest charges at Cleco Power.

Federal and state income taxes decreased $4.6 million, or 18.4%, during the third quarter of 2012 compared to the third quarter of 2011 primarily due to $2.9 million for the change in pre-tax income excluding AFUDC equity, $2.9 million for a favorable settlement with taxing authorities, $2.7 million for tax credits, and $0.4 million for miscellaneous items. These decreases were partially offset by $3.1 million for the tax returns filed and $1.2 million to record tax expense at the projected annual effective tax rate.

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

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Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2012			2011				VARIANCE			CHANGE
Operating revenue
Base	$	180,276		$	178,159			$	2,117		1.2	%
Fuel cost recovery	102,618			146,373				(43,755		)	(29.9	)%
Electric customer credits	(930		)	1,852				(2,782		)	(150.2	)%
Other operations	14,905			15,565				(660		)	(4.2	)%
Affiliate revenue	343			347				(4		)	(1.2	)%
Operating revenue, net	297,212			342,296				(45,084		)	(13.2	)%
Operating expenses
Fuel used for electric generation – recoverable	78,902			121,739				42,837			35.2	%
Power purchased for utility customers – recoverable	23,706			24,627				921			3.7	%
Non-recoverable fuel and power purchased	10,347			1,881				(8,466		)	(450.1	)%
Other operations	29,063			30,451				1,388			4.6	%
Maintenance	16,095			15,768				(327		)	(2.1	)%
Depreciation	33,199			29,539				(3,660		)	(12.4	)%
Taxes other than income taxes	8,390			8,802				412			4.7	%
Gain on sale of assets	—			(6		)		(6		)	(100.0	)%
Total operating expenses	199,702			232,801				33,099			14.2	%
Operating income	$	97,510		$	109,495			$	(11,985	)	(10.9	)%
Allowance for other funds used during construction	$	1,882		$	902			$	980		108.6	%
Interest charges	$	21,962		$	25,306			$	3,344		13.2	%
Federal and state income taxes	$	19,740		$	31,656			$	11,916		37.6	%
Net income	$	57,783		$	53,833			$	3,950		7.3	%

Cleco Power’s net income in the third quarter of 2012 increased $4.0 million, or 7.3%, compared to the third quarter of 2011. Contributing factors include:

•lower interest charges,

•higher base revenue,

•lower other operations expenses,

• higher allowance for other funds used during construction, and

•lower effective income tax rate.

These factors were partially offset by:

•higher non-recoverable fuel and power purchased,

•higher depreciation expense,

•higher electric customer credits, and

•lower other operations revenue.

	FOR THE THREE MONTHS ENDED SEPT. 30,
(MILLION kWh)	2012		2011		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	1,202		1,274		(5.7	)%
Commercial	784		796		(1.5	)%
Industrial	582		619		(6.0	)%
Other retail	36		36		—
Total retail	2,604		2,725		(4.4	)%
Sales for resale	616		652		(5.5	)%
Unbilled	(69	)	(129	)	46.5	%
Total retail and wholesale customer sales	3,151		3,248		(3.0	)%

	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	96,954		$	99,144		(2.2	)%
Commercial	50,145			48,732			2.9	%
Industrial	21,993			22,468			(2.1	)%
Other retail	2,669			2,600			2.7	%
Surcharge	1,950			2,983			(34.6	)%
Other	(1,566		)	(1,578		)	0.8	%
Total retail	172,145			174,349			(1.3	)%
Sales for resale	12,459			11,455			8.8	%
Unbilled	(4,328		)	(7,645		)	43.4	%
Total retail and wholesale customer sales	$	180,276		$	178,159		1.2	%

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

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

	FOR THE THREE MONTHS ENDED SEPT. 30,
				2012 CHANGE
	2012	2011	NORMAL	PRIOR YEAR		NORMAL
Cooling-degree days	1,560	1,671	1,511	(6.6	)%	3.2	%

Base

Base revenue increased $2.1 million, or 1.2%, during the third quarter of 2012 compared to the third quarter of 2011 primarily due to an annual rate adjustment associated with Cleco's FRP.

Cleco Power expects new industrial load to be added during the remainder of 2012 and 2013, primarily driven by expected development of Haynesville shale discovered in northwestern Louisiana. In addition, Cleco Power expects to begin providing service to expansions of current customers’

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operations, as well as service to new customers. These expansions of service to current customers and service to new customers are expected to contribute base revenue of $0.8 million during the remainder of 2012 and an additional $1.3 million in 2013, $0.6 million in 2014 and $5.3 million in 2015. Cleco Power also anticipates up to an additional $1.0 million of base revenue for the remainder of 2012 associated with the completed portions of the Acadiana Load Pocket transmission project. For information on the effects of future energy sales on Cleco Power’s financial condition, results of operations, and cash flows, see “Risk Factors — Future Electricity Sales” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Fuel Cost Recovery

Fuel cost recovery revenue billed to customers decreased $43.8 million, or 29.9%, during the third quarter of 2012 compared to the third quarter of 2011 primarily due to decreases in the per-unit cost of fuel used for electric generation and power purchased for utility customers. Also contributing to the decrease were lower volumes of fuel used for electric generation. Partially offsetting the decrease were higher volumes of power purchased for utility customers. Changes in fuel costs historically have not significantly affected Cleco Power’s net income. Generally, fuel and purchased power expenses are recovered through the LPSC-established fuel adjustment clause, which enables Cleco Power to pass on to its customers substantially all such charges. Approximately 89% of Cleco Power’s total fuel cost during the third quarter of 2012 was regulated by the LPSC, while the remainder was regulated by FERC. Recovery of fuel adjustment clause costs is subject to refund until approval is received from the LPSC.

Electric Customer Credits

Electric customer credits increased $2.8 million, or 150.2%, during the third quarter of 2012 compared to the third quarter of 2011 primarily due to the absence of a 2011 decrease in the customer credit accrual and an increase in the current year estimated accrual. For more information on the accrual for electric customer credits, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 9 — Electric Customer Credits.”

Other Operations

Other operations revenue decreased $0.7 million, or 4.2%, in the third quarter of 2012 compared to the third quarter of 2011 primarily due to $4.1 million related to lower mineral lease payments, $1.3 million related to the absence of a gain on the sale of Cleco Power’s fuel oil inventory and $0.4 million related to other miscellaneous revenue. Partially offsetting these amounts was $5.1 million related to an increase in wholesale power sales.

Operating Expenses

Operating expenses decreased $33.1 million, or 14.2%, in the third quarter of 2012 compared to the third quarter of 2011. Fuel used for electric generation (recoverable) decreased $42.8 million, or 35.2%, primarily due to lower per unit costs and volumes of fuel used for electric generation as compared to the third quarter of 2011. Power purchased for utility customers (recoverable) decreased $0.9 million, or 3.7%, largely due to lower per unit costs of purchased power. Partially offsetting this decrease was higher volumes of

purchased power. Fuel used for electric generation and power purchased for utility customers generally are influenced by natural gas prices, as well as availability of transmission. However, other factors such as scheduled and/or unscheduled outages, unusual maintenance or repairs, or other developments may affect fuel used for electric generation and power purchased for utility customers. Non-recoverable fuel and power purchased increased $8.5 million, or 450.1%, primarily due to higher non-recoverable wholesale power capacity costs. Other operations expense decreased $1.4 million, or 4.6%, primarily due to lower employee and payroll benefit expenses. Depreciation expense increased $3.7 million, or 12.4%, primarily due to the reclassification of the Acadia acquisition adjustment amortization and normal recurring additions to fixed assets.

Allowance for Other Funds Used During Construction

Allowance for other funds used during construction increased $1.0 million, or 108.6%, during the third quarter of 2012 compared to the third quarter of 2011 primarily due to higher AFUDC accruals related to the AMI Project and miscellaneous transmission projects, partially offset by lower amounts from the Acadiana Load Pocket Project and the absence of accruals related to the completion of Teche Unit 4.

Interest Charges

Interest charges decreased $3.3 million, or 13.2%, during the third quarter of 2012 compared to the third quarter of 2011 primarily due to $2.3 million related to reacquired debt in October and December 2011, $1.9 million related to uncertain tax positions, and $0.9 million related to the retirement of pollution control bonds in January and May 2012. Partially offsetting these decreases was $1.8 million related to the issuance of private placement notes in December 2011 and May 2012.

Income Taxes

Federal and state income taxes decreased $11.9 million, or 37.6%, during the third quarter of 2012 compared to the third quarter of 2011. The decrease is primarily due to $3.8 million for tax returns filed, $3.4 million for the change in pre-tax income excluding AFUDC equity, $2.9 million for a favorable settlement with taxing authorities, $1.7 million for tax credits, and $1.0 million to record tax expense at the projected annual effective rate. These decreases were partially offset by $0.9 million for miscellaneous items.

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Midstream
	FOR THE THREE MONTHS ENDED SEPT. 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2012			2011			VARIANCE			CHANGE
Operating revenue
Tolling operations	$	13,890		$	9,133		$	4,757		52.1	%
Other operations	1			1			—			—
Operating revenue	13,891			9,134			4,757			52.1	%
Operating expenses
Other operations	2,027			2,121			94			4.4	%
Maintenance	3,903			(1,131		)	(5,034		)	(445.1	)%
Depreciation	1,499			1,457			(42		)	(2.9	)%
Taxes other than income taxes	612			620			8			1.3	%
Gain on sale of assets	(2		)	(62		)	(60		)	(96.8	)%
Total operating expenses	8,039			3,005			(5,034		)	(167.5	)%
Operating income	$	5,852		$	6,129		$	(277	)	(4.5	)%
Other income	$	—		$	1,012		$	(1,012	)	(100.0	)%
Interest charges	$	(69	)	$	752		$	821		109.2	%
Federal and state income tax expense	$	2,489		$	444		$	(2,045	)	(460.6	)%
Net income	$	3,429		$	5,946		$	(2,517	)	(42.3	)%

Factors affecting Midstream during the third quarter of 2012 are described below.

Operating Revenue

Operating revenue increased $4.8 million, or 52.1%, in the third quarter of 2012 compared to the third quarter of 2011 primarily due to higher tolling revenue at Evangeline resulting from the new power purchase agreement with Cleco Power for Units 6 and 7 that began in January 2012 as compared to the Evangeline 2010 Tolling Agreement with JPMVEC for Unit 7.

Operating Expenses

Operating expenses increased $5.0 million, or 167.5%, in the third quarter of 2012 compared to the third quarter of 2011 primarily due to higher maintenance expenses at Evangeline resulting from the absence in 2012 of a 2011 insurance recovery related to outage expenses incurred during 2011.

Other Income

Other income decreased $1.0 million, or 100.0%, in the third quarter of 2012 compared to the third quarter of 2011 due to the absence in 2012 of the contractual expiration of an underlying indemnification resulting from the disposition of Acadia Unit 1.

Interest Charges

Interest charges decreased $0.8 million, or 109.2%, during the third quarter of 2012 compared to the third quarter of 2011 primarily related to uncertain tax positions.

Income Taxes

Federal and state income taxes increased $2.0 million, or 460.6%, during the third quarter of 2012 compared to the third quarter of 2011 primarily due to the tax returns filed. The effective income tax rate is different than the federal statutory rate due to state tax expense.

Comparison of the Nine Months Ended September 30, 2012 and 2011

Cleco Consolidated
			FOR THE NINE MONTHS ENDED SEPT. 30,
						FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2012			2011		VARIANCE			CHANGE
Operating revenue, net	$	760,265		$	878,193	$	(117,928	)	(13.4	)%
Operating expenses	528,381			628,597		100,216			15.9	%
Operating income	$	231,884		$	249,596	$	(17,712	)	(7.1	)%
Equity income from investees, before tax	$	1		$	62,051	$	(62,050	)	(100.0	)%
Other income	$	24,223		$	3,330	$	20,893		627.4	%
Interest charges	$	63,205		$	78,011	$	14,806		19.0	%
Federal and state income taxes	$	54,110		$	73,451	$	19,341		26.3	%
Net income applicable to common stock	$	140,536		$	165,067	$	(24,531	)	(14.9	)%

Consolidated net income applicable to common stock decreased $24.5 million, or 14.9%, in the first nine months of 2012 compared to the first nine months of 2011 primarily due to lower Midstream earnings. Partially offsetting this decrease were higher Cleco Power and corporate earnings.

Operating revenue, net decreased $117.9 million, or 13.4%, in the first nine months of 2012 compared to the first nine months of 2011 largely as a result of lower fuel cost recovery revenue at Cleco Power.

Operating expenses decreased $100.2 million, or 15.9%, in the first nine months of 2012 compared to the first nine months of 2011 primarily due to lower per unit costs and volumes of fuel used for electric generation.

Equity income from investees, before tax, decreased $62.1 million, or 100.0%, in the first nine months of 2012 compared to the first nine months of 2011 primarily due to the absence of the gain from the disposition of Acadia Unit 2 during the first nine months of 2011.

Other income increased $20.9 million, or 627.4%, in the first nine months of 2012 compared to the first nine months of 2011 largely as a result of the contractual expiration of underlying indemnifications resulting from the disposition of Acadia Units 1 and 2.

Interest charges decreased $14.8 million, or 19.0%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to lower interest charges at Cleco Power.

Federal and state income taxes decreased $19.3 million, or 26.3%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to $17.1 million for the change in pre-tax income excluding AFUDC equity, $5.9 million for tax credits, $1.6 million for a favorable settlement with taxing authorities, and $0.7 million for miscellaneous items. These decreases were partially offset by $3.1 million for the tax returns filed, $1.6 million to record tax expense at the projected annual effective tax rate, and $1.3 million for the absence in 2012 of the valuation allowance reversal booked in 2011.

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

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Cleco Power
				FOR THE NINE MONTHS ENDED SEPT. 30,
								FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2012				2011				VARIANCE			CHANGE
Operating revenue
Base	$	465,800			$	470,166			$	(4,366	)	(0.9	)%
Fuel cost recovery	254,976				353,318				(98,342		)	(27.8	)%
Electric customer credits	1,025				(3,405		)		4,430			130.1	%
Other operations	36,967				40,261				(3,294		)	(8.2	)%
Affiliate revenue	1,030				1,041				(11		)	(1.1	)%
Operating revenue, net	759,798				861,381				(101,583		)	(11.8	)%
Operating expenses
Fuel used for electric generation - recoverable	205,785				295,160				89,375			30.3	%
Power purchased for utility customers - recoverable	49,186				58,145				8,959			15.4	%
Non-recoverable fuel and power purchased	17,981				5,294				(12,687		)	(239.6	)%
Other operations	82,647				85,162				2,515			3.0	%
Maintenance	51,739				53,962				2,223			4.1	%
Depreciation	93,847				86,650				(7,197		)	(8.3	)%
Taxes other than income taxes	26,004				25,585				(419		)	(1.6	)%
Gain on sale of assets	(1		)		(7		)		(6		)	(85.7	)%
Total operating expenses	527,188				609,951				82,763			13.6	%
Operating income	$	232,610			$	251,430			$	(18,820	)	(7.5	)%
Other income	$	3,511			$	2,168			$	1,343		61.9	%
Interest charges	$	61,253			$	74,029			$	12,776		17.3	%
Federal and state income taxes	$	54,748			$	61,935			$	7,187		11.6	%
Net income	$	121,873			$	119,557			$	2,316		1.9	%

Cleco Power's net income in the first nine months of 2012 increased $2.3 million, or 1.9%, compared to the first nine months of 2011. Contributing factors include:

•lower interest charges,

•lower other operations and maintenance expenses,

•lower electric customer credits,

•higher other income, and

•lower effective income tax rate.

These were partially offset by:

• higher non-recoverable fuel and power purchased,

• higher depreciation expense,

• lower base revenue, and

• lower other operations revenue.

	FOR THE NINE MONTHS ENDED SEPT. 30,
(Million kWh)	2012	2011		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	2,834	3,105		(8.7	)%
Commercial	2,021	2,037		(0.8	)%
Industrial	1,710	1,770		(3.4	)%
Other retail	101	103		(1.9	)%
Total retail	6,666	7,015		(5.0	)%
Sales for resale	1,472	1,495		(1.5	)%
Unbilled	11	(90	)	112.2	%
Total retail and wholesale customer sales	8,149	8,420		(3.2	)%

	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	219,494		$	235,672		(6.9	)%
Commercial	136,208			137,133			(0.7	)%
Industrial	63,217			64,323			(1.7	)%
Other retail	7,436			7,484			(0.6	)%
Surcharge	6,801			7,534			(9.7	)%
Other	(4,686		)	(4,875		)	3.9	%
Total retail	428,470			447,271			(4.2	)%
Sales for resale	35,954			34,433			4.4	%
Unbilled	1,376			(11,538		)	111.9	%
Total retail and wholesale customer sales	$	465,800		$	470,166		(0.9	)%

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

			FOR THE NINE MONTHS ENDED SEPT. 30,
				2012 CHANGE
	2012	2011	NORMAL	PRIOR YEAR		NORMAL
Heating-degree days	500	937	940	(46.6	)%	(46.8	)%
Cooling-degree days	2,954	3,016	2,531	(2.1	)%	16.7	%

Base

Base revenue decreased $4.4 million, or 0.9%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to lower electric sales, generally resulting from milder winter weather in 2012. Partially offsetting this decrease was an annual rate adjustment associated with Cleco's FRP. For information on the anticipated effects of changes in base revenue in future periods, see “— Comparison of the Three Months Ended September 30, 2012 and 2011 — Cleco Power — Base.” For information on the effects of future energy sales on Cleco Power's financial condition, results of operations, and cash flows, see “Risk Factors — Future Electricity Sales” in the Registrants' Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Fuel Cost Recovery

Fuel cost recovery revenue billed to customers decreased $98.3 million, or 27.8%, during the first nine months of 2012 compared to the first nine months in 2011 primarily due to decreases in the per-unit cost of fuel used for electric generation and power purchased for utility customers. Also contributing to the decrease were lower volumes of fuel used for electric generation. Partially offsetting the decrease were higher volumes of power purchased for utility customers. For information on Cleco Power's ability to recover fuel and purchase power costs, see “— Comparison of the Three Months Ended September 30, 2012 and 2011 — Cleco Power — Fuel Cost Recovery.”

Electric Customer Credits

Electric customer credits decreased $4.4 million, or 130.1%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to the reversal of an estimated accrual and fuel audit reserves and the absence of the 2011 rate refunds. For additional information on the accrual of electric customer credits, see Item 1, “Notes to the Unaudited

49

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

Condensed Consolidated Financial Statements — Note 9 — Electric Customer Credits.”

Other Operations

Other operations revenue decreased $3.3 million, or 8.2%, in the first nine months of 2012 compared to the first nine months of 2011 primarily due to $5.7 million related to lower mineral lease payments, $4.4 million related to the absence of a gain on the sale of Cleco Power's fuel oil inventory, and $2.6 million related to lower transmission revenue. Partially offsetting these amounts were $7.9 million related to an increase in wholesale power sales and $1.5 million related to other miscellaneous revenue.

Operating Expenses

Operating expenses decreased $82.8 million, or 13.6%, in the first nine months of 2012 compared to the first nine months of 2011. Fuel used for electric generation (recoverable) decreased $89.4 million, or 30.3%, primarily due to lower per unit costs and volumes of fuel used as compared to the first nine months of 2011. Power purchased for utility customers (recoverable) decreased $9.0 million, or 15.4%, largely due to lower per-unit costs of purchased power. Partially offsetting this decrease was higher volumes of purchased power. Fuel used for electric generation and power purchased for utility customers generally are influenced by natural gas prices, as well as availability of transmission. However, other factors such as scheduled and/or unscheduled outages, unusual maintenance or repairs, or other developments may affect fuel used for electric generation and power purchased for utility customers. Non-recoverable fuel and purchased power increased $12.7 million, or 239.6%, primarily due to higher non-recoverable wholesale power purchases and other capacity payments. Other operations expense decreased $2.5 million, or 3.0%, primarily due to lower customer service expenses. Maintenance expense decreased $2.2 million, or 4.1%, primarily due to lower generating station and distribution maintenance work performed during the first nine months of 2012. Depreciation expense increased $7.2 million, or 8.3%, primarily due to Teche Unit 4 and portions of the Acadiana Load Pocket project being placed in service and other normal recurring additions to fixed assets and the reclassification of the Acadia acquisition adjustment amortization. Taxes other than income taxes increased $0.4 million, or 1.6%, primarily due to higher property taxes.

Other Income

Other income increased $1.3 million, or 61.9%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to higher royalty payments.

Interest Charges

Interest charges decreased $12.8 million, or 17.3%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to $9.1 million related to uncertain tax positions, $6.7 million related to reacquired debt in October and December 2011, $1.6 million related to the retirement of pollution control bonds in January and May 2012, and $0.1 million of higher other net miscellaneous interest charges. Partially offsetting these decreases was $4.7 million related to the issuance of private placement notes in December 2011 and May 2012.

Income Taxes

Federal and state income taxes decreased $7.2 million, or 11.6%, during the first nine months of 2012 compared to the first nine months of 2011. The decrease is primarily due to $3.8 million for tax returns filed, $2.1 million for the change in pre-tax income excluding AFUDC equity, $1.6 million for a favorable settlement with taxing authorities, $1.3 million for tax credits, and $0.2 million to record tax expense at the projected annual effective tax rate. These decreases were partially offset by $1.3 million for the absence in 2012 of the valuation allowance reversal booked in 2011 and $0.5 million for other miscellaneous items.

Midstream
	FOR THE NINE MONTHS ENDED SEPT. 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2012			2011			VARIANCE			CHANGE
Operating revenue
Tolling operations	$	21,434		$	16,137		$	5,297		32.8	%
Other operations	2			8			(6		)	(75.0	)%
Affiliate revenue	—			45			(45		)	(100.0	)%
Operating revenue	21,436			16,190			5,246			32.4	%
Operating expenses
Fuel used for electric generation	304			—			(304		)	—
Power purchased for utility customers	9			—			(9		)	—
Other operations	5,684			5,999			315			5.3	%
Maintenance	9,528			5,535			(3,993		)	(72.1	)%
Depreciation	4,491			4,370			(121		)	(2.8	)%
Taxes other than income taxes	1,896			1,880			(16		)	(0.9	)%
Gain on sale of assets	(45		)	(556		)	(511		)	(91.9	)%
Total operating expenses	21,867			17,228			(4,639		)	(26.9	)%
Operating loss	$	(431	)	$	(1,038	)	$	607		58.5	%
Equity income from investees, before tax	$	—		$	62,053		$	(62,053	)	(100.0	)%
Other income	$	19,016		$	1,534		$	17,482		*
Interest charges	$	244		$	1,963		$	1,719		87.6	%
Federal and state income tax expense	$	7,278		$	21,296		$	14,018		65.8	%
Net income	$	11,053		$	39,274		$	(28,221	)	(71.9	)%
* Not meaningful

Factors affecting Midstream during the first nine months of 2012 are described below.

Operating Revenue

Operating revenue increased $5.2 million, or 32.4%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to higher tolling revenue at Evangeline resulting from the new power purchase agreement with Cleco Power for Units 6 and 7 that began in January 2012 as compared to the Evangeline 2010 Tolling Agreement with JPMVEC for Unit 7.

Operating Expenses

Operating expenses increased $4.6 million, or 26.9%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to higher maintenance expenses at Evangeline due to higher turbine expenses, higher outage expenses and lower gain on sale of assets. Partially offsetting this increase is the absence of compressor blade damages.

50

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

Equity Income from Investees

Equity income from investees, before tax, decreased $62.1 million, or 100.0%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to the absence of the gain from the disposition of Acadia Unit 2 during the first nine months of 2011.

Other Income

Other income increased $17.5 million during the first nine months of 2012 compared to the first nine months of 2011 as a result of the contractual expiration of underlying indemnifications resulting from the disposition of Acadia Units 1 and 2.

Interest Charges

Interest charges decreased $1.7 million, or 87.6%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to uncertain tax positions.

Income Taxes

Federal and state income taxes decreased $14.0 million, or 65.8%, during the first nine months of 2012 compared to the first nine months of 2011 primarily due to a decrease in pre-tax income, partially offset by the tax returns filed. The effective income tax rate is different than the federal statutory rate due to state tax expense.

FINANCIAL CONDITION

Liquidity and Capital Resources

General Considerations and Credit-Related Risks

Credit Ratings and Counterparties

Financing for operational needs and capital expenditure requirements not satisfied by operating cash flows depends upon the cost and availability of external funds through both short- and long-term financing. The inability to raise capital on favorable terms could negatively affect Cleco’s or Cleco Power’s ability to maintain or expand its businesses. Access to funds is dependent upon factors such as general economic and capital market conditions, regulatory authorizations and policies, Cleco Corporation’s and Cleco Power’s credit ratings, the cash flows from routine operations, and the credit ratings of project counterparties. After assessing the current operating performance, liquidity, and credit ratings of Cleco Corporation and Cleco Power, management believes that Cleco Corporation and Cleco Power will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. The following table presents the credit ratings of Cleco Corporation and Cleco Power at September 30, 2012.

	SENIOR UNSECURED DEBT
	MOODY’S	STANDARD & POOR’S
Cleco Corporation	Baa3	BBB-
Cleco Power	Baa2	BBB

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

During the nine-months ended September 30, 2012, there were no changes to Cleco Corporation or Cleco Power’s credit ratings. At September 30, 2012, Moody’s outlooks for both

Cleco Corporation and Cleco Power were stable. On August 24, 2012, Standard & Poor's upgraded their outlooks for both Cleco Corporation and Cleco Power from stable to positive. Cleco Corporation and Cleco Power pay fees and interest under their bank credit agreements based on the highest rating held. If Cleco Corporation or Cleco Power’s credit rating were to be downgraded by Moody's and Standard & Poor’s, Cleco Corporation and/or Cleco Power would be required to post additional fees and incur higher interest rates under their 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 Standard & Poor’s, Cleco Power would be required to post additional collateral for derivatives.

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

Global and U.S. Economic Environment

The current economic environment and uncertainty may have an impact on Cleco’s business and financial condition. Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. Market conditions during the past few years have limited the availability and have increased the costs of capital for many companies. Although the Registrants have not experienced restrictions in the financial markets, their ability to access the capital markets may be restricted at a time when the Registrants would like, or need, to do so. Any restrictions could have a material impact on the Registrants’ ability to fund capital expenditures or debt service, or on their flexibility to react to changing economic and business conditions. Credit constraints could have a material negative impact on the Registrants’ lenders or customers, causing them to fail to meet their obligations to the Registrants or to delay payment of such obligations. The lower interest rates that the Registrants have been exposed to have been beneficial to recent debt issuances; however, these rates have negatively affected interest income for the Registrants’ short-term investments.

Fair Value Measurements

Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP.  Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the consolidated balance sheets with their fair values as of the balance sheet date disclosed within the three levels. For more information about fair value levels, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 4 — Fair Value Accounting.”

51

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

Cash Generation and Cash Requirements

Restricted Cash and Cash Equivalents

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

(THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
Diversified Lands’ mitigation escrow	$	97	$	97
Cleco Katrina/Rita’s storm recovery bonds	3,406		8,761
Cleco Power’s future storm restoration costs	11,510		24,876
Cleco Power’s renewable energy grant	—		381
Cleco Power’s NOx allowance escrow	1,713		1,713
Total restricted cash and cash equivalents	$	16,726	$	35,828

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 operating expenses, interest, and principal on storm recovery bonds. During the nine months ended September 30, 2012, Cleco Katrina/Rita collected $14.7 million net of operating expenses. In March and September 2012, Cleco Katrina/Rita used $6.7 million and $6.4 million, respectively, for scheduled storm recovery bond principal payments and $3.6 million and $3.4 million, respectively, for related interest.  Cleco Power's restricted cash and cash equivalents held for future storm restoration costs decreased $13.4 million from December 31, 2011, primarily due to the transfer of $4.5 million to restricted investments and the transfer of $10.0 million to cover expenses associated with Hurricane Isaac. These amounts were partially offset by $1.1 million of storm surcredits. For more information about these restricted investments, see Item 1, "Notes to the Unaudited Condensed Consolidated Financial Statements — Note 4 — Fair Value Accounting — Restricted Investments” and for more information about Hurricane Isaac, see Item 1, "Notes to the Unaudited Condensed Consolidated Financial Statements — Note 14 — Storm Restoration."

Debt

Cleco Consolidated

Cleco had no short-term debt outstanding at September 30, 2012 or December 31, 2011.

At September 30, 2012, Cleco’s long-term debt outstanding was $1.33 billion, of which $90.9 million was due within one year, compared to $1.36 billion outstanding at December 31, 2011, which included $24.3 million due within one year. The long-term debt due within one year at September 30, 2012, represents $75.0 million in senior notes due May 1, 2013, $14.0 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $1.9 million of capital lease payments. For Cleco, long-term debt decreased $33.2 million primarily due to $50.1 million of DeSoto Parish pollution control bonds that were redeemed in May 2012 and $11.2 million of Rapides Parish pollution control bonds that were redeemed in January 2012. Also contributing to the decrease was a $10.0 million reduction in credit facility draws, and $13.1 million of scheduled Cleco Katrina/Rita storm recovery bond principal payments made in March and September 2012. These decreases were partially offset by the issuance of $50.0 million of senior notes in May 2012, $0.5

million of capital lease payments and debt premium amortizations of $0.7 million.

On January 25, 2012, Cleco Power redeemed at par $11.2 million of 5.875% Rapides Parish pollution control bonds due September 2029. As part of the redemption, Cleco Power paid $0.3 million of accrued interest on the redeemed notes.

On May 8, 2012, Cleco Power issued $50.0 million senior unsecured private placement notes at an interest rate of 4.33%. The maturity date of the notes is May 15, 2027. The proceeds were used primarily for the early redemption of $50.1 million of 5.875% DeSoto Parish pollution control bonds as described above.

On May 11, 2012, Cleco Power redeemed at par all $50.1 million of 5.875% DeSoto Parish pollution control bonds due September 2029. As part of the redemption, Cleco Power paid $0.6 million of accrued interest on the redeemed notes.

Cash and cash equivalents available at September 30, 2012, were $68.4 million combined with $550.0 million facility capacity ($250.0 million from Cleco Corporation and $300.0 million from Cleco Power) for total liquidity of $618.4 million. Cash and cash equivalents available at September 30, 2012, decreased$25.2 million when compared to cash and cash equivalents available at December 31, 2011. This decrease is primarily due to additions to property, plant, and equipment, the net repayment of debt, and payment of common stock dividends.

At September 30, 2012, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents. In order to mitigate potential credit risk, Cleco and Cleco Power have established guidelines for short-term investments. For more information on the concentration of credit risk through short-term investments classified as cash equivalents, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 4 — Fair Value Accounting.”

At September 30, 2012 and December 31, 2011, Cleco had a working capital surplus of $149.6 million and $135.8 million, respectively. The $13.8 millionincrease in working capital is primarily due to:

• a $44.6 million net increase related to changes in the recognition of current taxes and uncertain tax positions and related interest charges expected to be settled in the next 12 months,

• a $24.9 million decrease in accounts payable primarily due to year-end pending ad valorem tax payments, employee incentive payments and fuel payments,

• a $24.8 million reduction in the deferred construction carrying costs owed to customers,

• an $11.4 million increase in fuel inventory due to dispatching lower cost natural gas-fired units, and

• a $9.8 million increase in customer accounts receivable which reflects the seasonal sales differences between December and September.

These increases in working capital were partially offset by:

• a $66.7 million increase in long-term debt due within one year primarily due to $75.0 million of senior notes that are due in May 2013,

• a $25.2 million decrease in unrestricted cash and cash equivalents as discussed above, and

• an $11.7 million increase in accrued interest, excluding interest on uncertain tax positions, due to timing of debt service schedules.

52

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

Cleco Corporation (Holding Company Level)

Cleco Corporation had no short-term debt outstanding at September 30, 2012 or December 31, 2011.

At September 30, 2012, Cleco Corporation had no draws outstanding under its $250.0 million credit facility compared to $10.0 million outstanding at December 31, 2011. This facility provides for working capital and other needs. Cleco Corporation and Cleco Power have uncommitted lines of credit with a bank that allow up to $10.0 million each in short term borrowings, but no more than $10.0 million in aggregate, to support their working capital needs.

Cash and cash equivalents available at September 30, 2012, were $15.1 million. Cash and cash equivalents available at September 30, 2012, decreased$7.6 million when compared to cash and cash equivalents available at December 31, 2011, primarily due to routine working capital fluctuations.

Cleco Power

Cleco Power had no short-term debt outstanding at September 30, 2012 or December 31, 2011.

At September 30, 2012, Cleco Power’s long-term debt outstanding was $1.33 billion, of which $90.9 million was due within one year, compared to $1.35 billion at December 31, 2011, of which $24.3 million was due within one year. The long-term debt due within one year at September 30, 2012, represents $75.0 million in senior notes due May 1, 2013, $14.0 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $1.9 million of capital lease payments. For Cleco Power, long-term debt decreased$23.2 million primarily due to $50.1 million of DeSoto Parish pollution control bonds that were redeemed in May 2012 and $11.2 million of Rapides Parish pollution control bonds that were redeemed in January 2012. Also contributing to the decrease was $13.1 million scheduled of Cleco Katrina/Rita storm recovery bond principal payments made in March and September 2012. These decreases were partially offset by the issuance of $50.0 million of senior notes in May 2012, $0.5 million of capital lease payments and debt premium amortizations of $0.7 million.

On January 25, 2012, Cleco Power redeemed at par $11.2 million of 5.875% Rapides Parish pollution control bonds due September 2029. As part of the redemption, Cleco Power paid $0.3 million of accrued interest on the redeemed notes.

On May 8, 2012, Cleco Power issued $50.0 million senior unsecured private placement notes at an interest rate of 4.33%. The maturity date of the notes is May 15, 2027. The proceeds were used primarily for the early redemption of $50.1 million of 5.875% DeSoto Parish pollution control bonds as described above.

On May 11, 2012, Cleco Power redeemed at par all $50.1 million of 5.875% DeSoto Parish pollution control bonds due September 2029. As part of the redemption, Cleco Power paid $0.6 million of accrued interest on the redeemed notes.

At September 30, 2012 and December 31, 2011, there were no borrowings outstanding under Cleco Power’s $300.0 million credit facility. This facility provides for working capital and other needs. Cleco Corporation and Cleco Power have uncommitted lines of credit with a bank that allow up to $10.0 million each in short term borrowings, but no more than $10.0 million in aggregate, to support their working capital needs.

Cash and cash equivalents available at September 30, 2012, were $50.6 million, combined with $300.0 million facility capacity for total liquidity of $350.6 million. Cash and cash equivalents decreased$16.9 million, when compared to cash

and cash equivalents at December 31, 2011, primarily due to additions to property, plant, and equipment, payment of intercompany dividends, and the net repayment of debt.

At September 30, 2012 and December 31, 2011, Cleco Power had a working capital surplus of $75.4 million and$36.4 million, respectively.  The $39.0 millionincrease in working capital is primarily due to:

• a $64.0 million net increase related to changes in the recognition of current taxes and uncertain tax positions and related interest charges expected to be settled in the next 12 months,

• a $24.8 million reduction in the deferred construction carrying costs owed to customers,

• an $18.7 million decrease in accounts payable primarily due to year-end pending ad valorem tax payments, employee incentive payments and fuel payments,

• an $11.4 million increase in fuel inventory primarily due to dispatching of lower cost natural gas-fired units, and

• a $9.8 million increase in customer accounts receivable which reflects the seasonal sales differences between December and September.

These increases in working capital were partially offset by:

• a $66.7 million increase in long-term debt due within one year primarily due to $75.0 million of senior notes that are due May 2013,

• a $16.9 million decrease in unrestricted cash and cash equivalents, as discussed above, and

• an $11.8 million increase in accrued interest, excluding interest on uncertain tax positions, due to timing of debt service schedules.

Credit Facilities

Cleco Corporation’s current credit facility agreement has a maximum capacity of $250.0 million and a maturity date of October 7, 2016. The borrowing costs are LIBOR plus 1.50% or ABR plus 0.50%, plus facility fees of 0.25%. If Cleco Corporation’s credit ratings were to be downgraded one level, Cleco Corporation would be required to pay fees and interest at a rate of 0.25% higher than the level for its current credit facility.

Cleco Power’s current credit facility agreement has a maximum capacity of $300.0 million and matures on October 7, 2016. The borrowing costs are LIBOR plus 1.275% or ABR plus 0.275%, plus facility fees of 0.225%. If Cleco Power’s credit ratings were to be downgraded one level, Cleco Power would be required to pay fees and interest at a rate of 0.25% higher than the level on its current credit facility.

At September 30, 2012, Cleco Corporation and Cleco Power were in compliance with the covenants in their credit facilities. If Cleco Corporation were to default under the covenants in its credit facility or other debt agreements, it would be unable to borrow additional funds under the facility, and the lenders could accelerate all principal and interest outstanding. Further, if Cleco Power were to default under its credit facility or other debt agreements, Cleco Corporation would be considered in default under its credit facility.

Midstream

Midstream had no debt outstanding at September 30, 2012 or December 31, 2011.

53

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

Cleco Consolidated Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $224.6 million during the first nine months of 2012, compared to $263.6 million during the first nine months of 2011. Cash provided by operating activities during the first nine months of 2012 decreased$39.0 million from the first nine months of 2011, primarily due to the following items:

• the absence of the return on equity investment in Acadia of $58.7 million,

• the absence of 2011 fuel oil inventory sales of $31.4 million,

• higher expenditures for other fuel inventories and related transportation of $23.3 million, primarily petroleum coke and coal,

• the absence of $10.9 million cash received in exchange for accepting the contingent sale liability related to the Acadia Unit 2 transaction in 2011, and

• higher storm expenditures of $6.2 million.

These decreases were partially offset by:

• lower pension plan contributions of $60.0 million,

• lower tax payments of $18.4 million, and

• lower payments for gas purchases of $12.4 million.

Net Investing Cash Flow

Net cash used in investing activities was $149.2 million during the first nine months of 2012, compared to $55.0 million during the first nine months of 2011. Net cash used in investing activities during the first nine months of 2012 was higher than the first nine months of 2011 primarily due to the absence of the 2011 return of investment in Acadia, higher additions to property, plant, and equipment, higher contributions to the NMTC Fund, and purchases of restricted investments, partially offset by a higher return of investment in the NMTC Fund, higher property, plant, and equipment grants received, higher transfers of cash from restricted accounts, and a property loss insurance reimbursement.

During the first nine months of 2012, Cleco had additions to property, plant, and equipment, net of AFUDC of $172.8 million, a $46.9 million investment in the NMTC Fund, and purchases of restricted investments, net of premium and interest of $4.3 million. This was partially offset by a $37.1 million return of investment from the NMTC Fund, $19.1 million of cash transferred from restricted accounts, $15.1 million of grants received, and a $5.5 million property loss insurance reimbursement. The cash transferred from restricted accounts was primarily related to cash restricted for storm costs, restricted investments, and GO Zone bonds.

During the first nine months of 2011, Cleco had additions

to property, plant and equipment, net of AFUDC of $142.9 million and an $18.5 million investment in the NMTC Fund. This was partially offset by an $89.7 million return of equity investment in Acadia and the transfer of $12.1 million of

cash from restricted accounts, primarily related to GO Zone

bonds and cash restricted for storm costs.

Net Financing Cash Flow

Net cash used in financing activities was $100.6 million during the first nine months of 2012, compared to $241.4 million during the first nine months of 2011. Net cash used in

financing activities during the first nine months of 2012 was lower than the first nine months of 2011 primarily due to the absence of the 2011 repayment of a bank term loan, the issuance of long-term debt, lower payments on the credit facility, and lower repurchases of common stock. This was partially offset by higher retirements of long-term debt, the absence of draws on the credit facility, and higher dividends paid on common stock.

During the first nine months of 2012, Cleco retired $74.4 million of long-term bonds. Cleco also used $58.5 million for dividend payments, $10.0 million for payments on the credit facility, and $8.0 million for the repurchase of common stock. This was partially offset by the issuance of $50.0 million of long-term debt.

During the first nine months of 2011, Cleco repaid a

$150.0 million bank term loan and $37.3 million of long-term

debt, consisting of $25.0 million of credit facility draws and

$12.3 million of long-term bonds. Cleco also used $49.2 million

for the payment of common stock dividends and $13.0

million for the repurchase of common stock. This was partially

offset by $10.0 million in credit facility draws.

Cleco Power Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $205.5 million during the first nine months of 2012, compared to $185.6 million during the first nine months of 2011. Cash provided by operating activities during the first nine months of 2012 increased$19.9 million from the first nine months of 2011 primarily due to the following items:

• lower pension plan contributions of $60.0 million,

• lower payments for gas purchases of $12.4 million,

• the absence of tax movie credits purchased in 2011 of $4.0 million, and

• lower tax payments of $2.5 million.

These increases were partially offset by:

• the absence of 2011 fuel oil inventory sales of $31.4 million,

• higher expenditures for other fuel inventories and related transportation of $23.3 million, primarily petroleum coke and coal, and

• higher storm expenditures of $6.2 million.

Net Investing Cash Flow

Net cash used in investing activities was $138.3 million during the first nine months of 2012, compared to $113.8 million during the first nine months of 2011. Net cash used in investing activities during the first nine months of 2012 was higher than the first nine months of 2011 primarily due to higher additions to property, plant, and equipment and purchases of restricted investments, partially offset by higher property, plant, and equipment grants received and higher transfers of cash from restricted accounts.

During the first nine months of 2012, Cleco had additions to property, plant, and equipment, net of AFUDC of $169.0 million and purchases of restricted investments, net of premium and interest of $4.3 million. This was partially offset by $19.1 million of cash transferred from restricted accounts, primarily related to cash restricted for storm costs, restricted investments, and GO Zone bonds, and $15.1 million of grants received.

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During the first nine months of 2011, Cleco Power had additions to property, plant, and equipment, net of AFUDC of $128.2 million. This was partially offset by the transfer of $12.1 million of cash from restricted accounts, primarily related to GO Zone bonds and cash restricted for storm costs, and $1.6 million of grants received.

Net Financing Cash Flow

Net cash used in financing activities was $84.1 million during the first nine months of 2012, compared to $113.7 million during the first nine months of 2011. Net cash used in financing activities during the first nine months of 2012 was lower than the first nine months of 2011 primarily due to the issuance of long-term debt and $42.0 million of lower distributions made to Cleco Corporation, partially offset by higher repayments of long-term debt.

Contractual Obligations and Other Commitments

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

For more information regarding Cleco’s Contractual Obligations and Other Commitments, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Contractual Obligations and Other Commitments” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Off-Balance Sheet Commitments and Disclosures about Guarantees

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. For more information on off-balance sheet commitments, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 11 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Off-Balance Sheet Commitments” and “— Disclosures about Guarantees.”

Regulatory and Other Matters

Generation RFP

Renewable Energy Pilot Program

In November 2010, the LPSC established a two-part renewable energy pilot program implementation plan consisting of a research component and an RFP component. Cleco Power is meeting the requirements of the research component by developing eight self-build renewable energy projects, each with a maximum nameplate rating of 300 kilowatts. The RFP component of the program requires each LPSC jurisdictional utility to conduct an RFP for new long-term renewable resources, while prohibiting the utilities from bidding self-build projects into the long-term RFP. Cleco Power’s requirement is 43 MW of renewable energy with a minimum term of 10 years

and a maximum term of 20 years, and can reasonably be expected to be deliverable within the 2011-2014 time period. Because Madison Unit 3 is designed to burn biomass fuel, with minor modifications, in addition to its primary fuel, Cleco Power has been given an exception allowing it to conduct an RFP for biomass fuel along with identifying the costs to co-fire biomass fuel in Madison Unit 3. In November 2011, Cleco Power received LPSC approval for recovery of the test burn costs, and performed a biomass test burn at Madison Unit 3. Cleco Power issued its final RFP for biomass fuel in February 2012, and received all proposals by April 17, 2012. On August 3, 2012, Cleco Power filed a written report to the LPSC regarding co-firing biomass fuel in Madison Unit 3. Following its review of the results of Cleco Power’s RFP and Cleco Power's written report, the LPSC may authorize Cleco Power to pursue co-firing biomass fuel in Madison Unit 3 or require Cleco Power to conduct an additional RFP for 43 MW of renewable energy as discussed above. For more information on Cleco’s renewable energy pilot program, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Generation RFP” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

RFP for Short-Term 2012 Resources

In August 2011, Cleco Power issued an RFP for short-term 2012 resources to enhance reliability for the period January through April 2012. Cleco Power selected and negotiated two agreements from the RFP, a power purchase agreement with NRG Power Marketing LLC, and a tolling agreement with Evangeline. The NRG agreement provided 200 MW of capacity and energy from January 1, 2012 through April 30, 2012, while the Evangeline agreement provided 250 MW of capacity and energy from January 1, 2012 through April 30, 2012.

RFP for Contractual Resources Beginning in May 2012

In September 2011, Cleco Power issued a draft RFP for resources and conducted a bidders conference on October 13, 2011. The final RFP seeking up to approximately 750 MW of capacity and energy for a three- or five-year term was published on October 21, 2011. In March 2012, Cleco Power received approval from the LPSC for a three-year power purchase agreement providing 730 MW of capacity and energy with Evangeline for a delivery term beginning May 1, 2012 and ending April 30, 2015. Because Cleco Power and Evangeline are affiliates, Cleco Power also received approval from FERC to make power sales between affiliates pursuant to Section 205 of the Federal Power Act.

2012 Long-Term RFP for Capacity and Energy Resources

In May 2012, Cleco Power issued a draft RFP seeking up to approximately 800 MW beginning May 2015 to meet long-term capacity and energy needs due to load growth and environmental regulations. Cleco Power conducted a technical and bidders conference in May 2012, issued its final RFP in July 2012, and received proposals from potential suppliers in August 2012. On October 30, 2012, Cleco Power announced Evangeline as the winning bidder in Cleco Power's 2012 Long-Term RFP. For more information, see Item 1, "Notes to the Unaudited Condensed Consolidated Financial Statements — Note 15 — Subsequent Event."

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Environmental Matters

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

On August 21, 2012, the D.C. Circuit Court of Appeals issued a 2-1 opinion vacating and remanding CSAPR. The court opinion found that the rule exceeds the EPA’s authority under the Clean Air Act in two key areas: (1) CSAPR required upwind states to reduce their emissions beyond the amounts they were contributing to downwind states and, (2) the EPA's simultaneous issuance of the CSAPR rule and CSAPR federal implementation plans (FIPs) did not provide states adequate time to develop their own State Implementation Program (SIP) to address emission transport issues.  As such, CSAPR is vacated and the Clean Air Interstate Rule (CAIR) is reinstated in its place for now.  However, the D.C. Circuit Court ordered the EPA to rewrite the rule in an expeditious fashion to address the flaws of CSAPR. The EPA filed a petition seeking rehearing or rehearing “en banc” or by the full 8-judge panel instead of the 3-judge panel. If a rehearing is denied, the EPA will have 90 days to file a petition for a writ of certiorari seeking a Supreme Court review.  If the EPA is unsuccessful in the appeals process and undertakes rewriting a new rule, it is uncertain at this point what the new rule will entail. However, the EPA will be confined by the procedural requirements laid out by the Court's opinion. It is very likely that any compliance requirements of a new rule will be delayed for at least a year or more. Until then, CAIR remains in effect.

For a discussion of other Cleco environmental matters, please read “Business — Environmental Matters” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Retail Rates of Cleco Power

For information concerning amounts accrued and refunded by Cleco Power as a result of the FRP and information on the LPSC Staff’s FRP reviews, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 9 — Electric Customer Credits.”

For information on certain other regulatory aspects of retail rates concerning Cleco Power, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Retail Rates of Cleco Power” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Wholesale Rates of Cleco

Transmission Service

On March 29, 2012, Cleco Power filed a request with FERC for revisions to its Open Access Transmission Tariff (OATT). The revisions were proposed to allow adoption of a formula rate methodology for transmission delivery and ancillary services provided by Cleco Power under the OATT and the existing bilateral Electric System Interconnection Agreements that preceded the OATT. The new formula rates will permit recovery of Cleco Power’s FERC-jurisdictional investments in transmission and other assets placed in service since the existing rates were established. On May 31, 2012, FERC issued an order accepting the rates for scheduling, system control and dispatch service, and the loss factors effective June 1, 2012. The remaining proposed rates are suspended for the maximum five-month statutory period and will become effective November 1, 2012, subject to refund. Cleco Power has received and responded to a total of 107 data requests from FERC staff and intervenors and has participated in several settlement conferences. Cleco Power anticipates settlement of this rate proceeding in late 2012.

For more information on the wholesale rates of Cleco, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Wholesale Rates of Cleco” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Market Restructuring

Wholesale Electric Markets

Regional Transmission Organization

In 1999, FERC issued Order No. 2000, which established a general framework for all transmission-owning entities in the nation to voluntarily place their transmission facilities under the control of an appropriate RTO. Although participation was voluntary, FERC made it clear that any jurisdictional entity not participating in a RTO likely would be subject to regulatory directives. FERC later relaxed its mandate to participate in an RTO, but continued to insist upon large regional models. Many transmission-owning entities and system operators have been trying to interpret and implement FERC's directives by attempting to organize and/or join acceptable RTOs. In October 2004, FERC granted the SPP status as an RTO.

In April 2004, Entergy filed at FERC to make potentially significant modifications to its transmission tariff. The modifications would incorporate an independent third-party entity, the ICT, into its transmission operations, with the ICT having access to pertinent information regarding the Entergy transmission system. After receiving approval from FERC and state commissions (including the LPSC), the SPP began a four year trial as Entergy's acting ICT on November 17, 2006.

In early 2009, the Arkansas Public Service Commission directed SPP to perform a comprehensive Cost Benefit Analysis Study (CBA Study) of full SPP membership by all the Entergy operating companies as compared to participation under the existing ICT services arrangement and full SPP membership by Entergy Arkansas, Inc. as a standalone entity, compared to continuing under the existing ICT services arrangement. The study was completed on

September 30, 2010.

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Additional addendum studies were performed during 2011, which included all the Entergy operating companies joining the Midwest Independent System Operator (MISO) RTO. Based on these addendum studies, Entergy has announced that MISO provides more overall savings for their customers than SPP.

Entergy Arkansas, Entergy Gulf States, Entergy Louisiana, Entergy Mississippi, Entergy New Orleans, and Entergy Texas have made regulatory filings with their respective public service commissions indicating their intent to join MISO by January 1, 2014. In May 2012, the LPSC approved Entergy's membership in MISO, subject to protective conditions. On October 26, 2012, the Public Utility Commission of Texas conditionally approved Entergy Texas' proposal to join MISO. Also, on October 26, 2012, the Arkansas Public Service Commission conditionally approved Entergy Arkansas' request to join MISO leaving only two of Entergy's six electric utility companies awaiting approval from their respective public service commissions.

As with RTO developments at large, other various parties, including several state commissions, utilities, and other industry participants, are participants in the RTO and Entergy proceedings described above. Cleco anticipates submitting a regulatory filing with the LPSC indicating its intent to join MISO by January 1, 2014.

For more information on regulatory aspects of wholesale electric markets affecting Cleco, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Market Restructuring — Wholesale Electric Markets” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Retail Electric Markets

For a discussion of the regulatory aspects of retail electric markets affecting Cleco Power, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Market Restructuring — Retail Electric Markets” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Lignite Deferral

At September 30, 2012 and December 31, 2011, Cleco Power had $17.2 million and $19.1 million, respectively, in deferred lignite mining costs remaining uncollected.

For more information on Cleco Power’s deferred lignite mining expenditures, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Lignite Deferral” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Acadiana Load Pocket Project

In September 2008, Cleco Power entered into an agreement with two other utilities to upgrade and expand interconnected transmission systems in south central Louisiana in an area known as the Acadiana Load Pocket. The project received LPSC and SPP approval in February 2009. Cleco Power’s estimated cost for its portion of the project is $125.0 million, including AFUDC. As of September 30, 2012, Cleco Power had spent $119.6 million on the project. A return on and recovery of the costs associated with the completed portions of the Acadiana Load Pocket project are included in base

revenue. The project was substantially completed by the end of June 2012. Remaining portions of the project are expected to be complete by December 2012. For more information, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — Acadiana Load Pocket Project” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011. For information on the impact the Acadiana Load Pocket project is expected to have on base revenue, see “Results of Operations — Comparison of the Three Months Ended September 30, 2012 and 2011 — Cleco Power — Base.”

AMI Project

In May 2010, Cleco Power accepted the terms of a $20.0 million grant from the DOE under the DOE’s small-grant process to implement advanced metering technology for all of Cleco Power’s retail customers. Cleco Power estimates the project will cost $73.0 million, with the DOE grant providing $20.0 million toward the project and Cleco Power providing the remaining $53.0 million. The grant program is a part of the American Recovery and Reinvestment Act of 2009, an economic stimulus package passed by Congress in February 2009. Advanced metering technology includes the installation of electric meters that enable two-way communication capabilities between a home or business and a utility company. At September 30, 2012, Cleco Power had incurred $45.4 million in project costs, of which $20.0 million has been submitted to the DOE for reimbursement. As of September 30, 2012, Cleco Power had received $18.5 million in payments from the DOE. The project is expected to be completed in the third quarter of 2013. For more information, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Regulatory and Other Matters — AMI Project” in the Registrants' Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Financial Reform Legislation

In July 2010, the President signed the Dodd-Frank Act into law. Title VII of the Dodd-Frank Act established a comprehensive new regulatory framework for swaps and security-based swaps, including mandatory clearing, exchange trading, collateral requirements, margin requirements, and other transparency requirements. In July 2012, the Commodity Futures Trading Commission published final rules for the definition of a swap and for the end-user exemption. Management is reviewing the final and proposed rules that have been issued or will be issued under the Dodd-Frank Act and will continue to monitor this law and its possible impact on the Registrants.

Franchises

On March 13, 2012, the City of Slidell unanimously voted to renew the franchise agreement with Cleco Power. The renewal extends the agreement for 33 years until April 2045. Approximately 16,400 Cleco Power customers are located in Slidell.

On April 5, 2012, the City of Oakdale unanimously voted to renew the franchise agreement with Cleco Power. The renewal extends the agreement for 27 years until April 2039. Approximately 3,400 Cleco Power customers are located in Oakdale.

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On April 10, 2012, the Town of Berwick unanimously voted to renew the franchise agreement with Cleco Power. The renewal extends the agreement for 22 years until April 2034. Approximately 2,700 Cleco Power customers are located in Berwick.

For more information on other electric service franchises, please read “Business — Regulatory Matters, Industry Developments, and Franchises — Franchises” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

Other Franchise Matters

On March 9, 2010, a complaint was filed in the 27^th 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. In addition, on May 11, 2010, a second complaint repeating the allegations of the first was filed on behalf of a number of Opelousas residents. For more information regarding these complaints, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 11 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — City of Opelousas.”

Recent Authoritative Guidance

For a discussion of recent authoritative guidance, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 2 — Recent Authoritative Guidance” of this Combined Quarterly Report on Form 10-Q, which discussion is incorporated herein by reference.

CRITICAL ACCOUNTING POLICIES

Cleco’s critical accounting policies include those accounting policies that are both important to Cleco’s financial condition and results of operations and those that require management to make difficult, subjective, or complex judgments about future events, which could result in a material impact to the financial statements of Cleco Corporation’s segments or to Cleco as a consolidated entity.  The financial statements contained in this report are prepared in accordance with GAAP, which require Cleco to make estimates and assumptions.  Estimates and assumptions about future events and their effects cannot be made with certainty.  Management bases its current estimates and assumptions on historical experience and on various other factors that are believed to be reasonable under the circumstances.  On an ongoing basis, these estimates and assumptions are evaluated and, if necessary, adjustments are made when warranted by new or updated information or by a change in circumstances or environment.  Actual results may differ significantly from these estimates under different assumptions or conditions. 

In July 2012, a law was passed that changed the calculation of minimum pension funding requirements. The effect of this law will be to lower minimum funding requirements in the short-term (about two to three years). This law is not expected to impact overall minimum plan contributions over the long-term.

For more information on Cleco’s critical accounting policies, see “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Critical Accounting Policies” in the Registrant’s Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

CLECO POWER — NARRATIVE ANALYSIS OF RESULTS OF OPERATIONS

Set forth below is information concerning the results of operations of Cleco Power for the three and nine months ended September 30, 2012 and September 30, 2011. The following narrative analysis should be read in combination with Cleco Power’s Unaudited Condensed Consolidated Financial Statements and the Notes contained in this Combined Quarterly Report on Form 10-Q.

Cleco Power meets the conditions specified in General Instructions H(1)(a) and (b) to Form 10-Q and is therefore permitted to use the reduced disclosure format for wholly owned subsidiaries of reporting companies. Accordingly, Cleco Power has omitted from this report the information called for by Item 2 (Management’s Discussion and Analysis of Financial Condition and Results of Operations) and Item 3 (Quantitative and Qualitative Disclosures about Market Risk) of Part I of Form 10-Q and the following Part II items of Form 10-Q: Item 2 (Unregistered Sales of Equity Securities and Use of Proceeds) and Item 3 (Defaults upon Senior Securities). Pursuant to the General Instructions, Cleco Power has included an explanation of the reasons for material changes in the amount of revenue and expense items of Cleco Power between the first nine months of 2012 and the first nine months of 2011. Reference is made to Management’s Discussion and Analysis of Financial Condition and Results of Operations in Item 7 of the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011.

For an explanation of material changes in the amount of revenue and expense items of Cleco Power between the third quarter of 2012 and the third quarter of 2011, see “— Results of Operations — Comparison of the Three Months Ended September 30, 2012 and 2011 — Cleco Power” of this Combined Quarterly Report on Form 10-Q, which discussion is incorporated herein by reference.

For an explanation of material changes in the amount of revenue and expense items of Cleco Power between the first nine months of 2012 and the first nine months of 2011, see “— Results of Operations — Comparison of the Nine Months Ended September 30, 2012 and 2011 — Cleco Power” of this Combined Quarterly Report on Form 10-Q, which discussion is incorporated herein by reference.

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ITEM 3.QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

Risk Overview

Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power and natural gas in the industry on different energy exchanges.

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 since Cleco Power takes physical delivery and the instruments and positions are used to satisfy customer requirements. When positions close, actual gains or losses are included in the fuel adjustment clause and reflected on customers’ bills as a component of the fuel cost adjustment.

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

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

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. Market conditions during the past few years have limited the availability and have increased the costs of capital for many companies. The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain and expand its businesses. After assessing the current operating performance, liquidity, and credit ratings of Cleco, management believes that it will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. Cleco Corporation and Cleco Power pay fees and interest under their respective credit facilities based on the highest rating held. If Cleco Corporation or Cleco Power’s credit ratings were to be downgraded by Moody’s and Standard & Poor’s, Cleco Corporation or Cleco Power, as the case may be, would be required to pay additional fees and higher interest rates under their respective credit facilities. Cleco Power’s collateral for derivatives is based on the lowest rating held. If Cleco Power’s credit ratings were to be downgraded by Standard & Poor’s or Moody’s, Cleco Power would be required to pay additional collateral for derivatives.

Interest Rate Risks

Cleco monitors its mix of fixed- and variable-rate debt obligations in light of changing market conditions and from

time to time may alter that mix, for example, refinancing balances outstanding under its variable-rate credit facility with fixed-rate debt. For details, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 5 — Debt." Calculations of the changes in fair market value and interest expense of the debt securities are made over a one-year period.

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

At September 30, 2012, Cleco had no short-term variable rate debt outstanding.

At September 30, 2012, Cleco Corporation had no borrowings outstanding under its $250.0 million credit facility.

On November 14, 2011, Cleco Power entered into a forward starting interest rate swap contract in order to mitigate the interest rate exposure on coupon payments related to a $50.0 million fixed-rate forecasted debt issuance. The forward starting interest rate swap has 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 is earlier. The forward starting interest rate swap meets the criteria of a cash flow hedge under the authoritative guidance as it relates to derivatives and hedging. The fair market value of the forward starting interest rate swap is the difference between the present value of the fixed payments to be paid by Cleco Power and the present value of the three-month LIBOR payments to be received by Cleco Power. Cleco Power recognized a $0.8 million unrealized mark-to-market gain and a $0.7 million unrealized mark-to-market loss in other comprehensive income for the three and nine months ended September 30, 2012, respectively. The offsetting liability was recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets as an interest rate risk management liability. There was no impact to earnings due to ineffectiveness for the three and nine months ended September 30, 2012. For every 0.01% change in the three-month LIBOR forward curve, the value of the forward starting interest rate swap changes by approximately $0.1 million.

Commodity Price Risks

Management believes Cleco has controls in place to minimize the risks involved in its financial and energy commodity activities. Independent controls over energy commodity functions consist of a middle office (risk management), a back office (accounting), and regulatory compliance staff, as well as monitoring by a risk management committee comprised of officers, who are approved by Cleco Corporation’s Board of Directors. Risk limits are recommended by the Risk Management Committee and monitored through a daily risk report that identifies the current VaR, current market conditions, and concentration of energy market positions.

Cleco Power provides fuel for generation and purchases power to meet the power demands of customers. Cleco Power has entered into positions to mitigate the volatility in customer fuel costs, as encouraged by an LPSC order. Cleco Power’s fuel stabilization policy targets certain levels of hedging percentages to help mitigate the volatility in customer fuel costs. The change in positions could result in increased volatility in the marked-to-market amounts for the financial positions. These positions are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of the accumulated deferred fuel asset or liability

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CLECO POWER	2012 3RD QUARTER FORM 10-Q

and a component of the energy risk management assets or liabilities. When these positions close, actual gains or losses are deferred and included in the fuel adjustment clause in the month the physical contract settles. Based on market prices at September 30, 2012, there was no net mark-to-market impact related to open natural gas positions and at December 31, 2011, the net mark-to-market impact related to open natural gas positions was a loss of $5.3 million. There were no open natural gas positions at September 30, 2012. Deferred losses relating to closed natural gas positions at September 30, 2012 and December 31, 2011, totaled $0.1 million and $1.2 million, respectively.

Cleco utilizes a VaR model to assess the market risk of its hedging portfolios, including derivative financial instruments. VaR represents the potential loss in fair value for an instrument from adverse changes in market factors over a defined period of time with a specified confidence level. VaR is calculated daily, using the variance/covariance method with delta approximation, assuming a holding period of one day, and a 95% confidence level for natural gas and power positions. Volatility is calculated daily from historical forward prices using the exponentially weighted moving average method. Based on these assumptions, the VaR relating to Cleco Power’s hedge transactions for the three and nine months ended September 30, 2012, as well as the VaR at December 31, 2011, is summarized as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30, 2012
(THOUSANDS)	HIGH		LOW		AVERAGE
Fuel cost hedges	$	125.7	$	—	$	43.7

	FOR THE NINE MONTHS ENDED SEPT. 30, 2012						AT SEPT. 30, 2012		AT DEC. 31, 2011
(THOUSANDS)	HIGH		LOW		AVERAGE
Fuel cost hedges	$	382.0	$	—	$	167.7	$	—	$	196.1

Cleco Power

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

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

Cleco Power had no short- or long-term variable-rate debt as of September 30, 2012.

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

ITEM 4. CONTROLS AND PROCEDURES

Evaluation of Disclosure Controls and Procedures

As of September 30, 2012, evaluations were performed under the supervision and with the participation of Cleco Corporation and Cleco Power LLC (individually, “Registrant” and collectively, the “Registrants”) management, including the Chief Executive Officer (CEO) and Chief Financial Officer (CFO). The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures. Based on the evaluations, the CEO and CFO have concluded that the Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized, and reported within the time periods specified in SEC rules

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

Changes in Internal Control over Financial Reporting

There has been no change in the Registrants' internal control over financial reporting that occurred during the quarter ended September 30, 2012 that has materially affected, or is reasonably likely to materially affect, the Registrants' internal control over financial reporting.

60

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

PART II — OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

CLECO

For information on legal proceedings affecting Cleco, see Part

I, Item 1, “Notes to the Unaudited Condensed Consolidated

Financial Statements — Note 11 — Litigation, Other

Commitments and Contingencies, and Disclosures about

Guarantees — Litigation.”

CLECO POWER

For information on legal proceedings affecting Cleco Power,

see Part I, Item 1, “Notes to the Unaudited Condensed

Consolidated Financial Statements — Note 11 — Litigation,

Other Commitments and Contingencies, and Disclosures

about Guarantees — Litigation.”

ITEM 1A. RISK FACTORS

Other than the update to the risk factors below, there have been no material changes from the risk factors disclosed under the heading “Risk Factors” in Item 1A of the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2011 (the “2011 Annual Report on Form 10-K”). For additional risks that could affect actual results and cause results to differ materially from those expressed in any forward-looking statements made by, or on behalf of, the Registrants, see the risk factors disclosed under “Risk Factors” in Item 1A of the 2011 Annual Report on Form 10-K.

LPSC Audits

The LPSC conducts fuel audits that could result in Cleco Power making substantial refunds of previously recorded revenue. Generally, fuel and purchased power expenses are recovered through the LPSC-established fuel adjustment clause, which enables Cleco Power to pass on to its customers substantially all such expenses. Recovery of fuel adjustment clause costs is subject to a periodic fuel audit by the LPSC. The LPSC Fuel Adjustment Clause General Order issued November 6, 1997, in Docket No. U-21497 provides that an audit will be performed not less than every other year.

Cleco Power currently has fuel adjustment clause filings for 2009 through 2011 subject to audit. Management is not able to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. However, if a disallowance of fuel costs is ordered resulting in a refund, any such refund could have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows. The most recent fuel audit completed by the LPSC was for the years 2003 through 2008 and resulted in

Cleco Power making refunds of $0.4 million plus interest to customers during the September 2012 billing cycle.

The LPSC conducts environmental audits that could result in Cleco Power making substantial refunds of previously recorded revenue.

In July 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides for an Environmental Adjustment Clause to recover certain costs of environmental compliance as an adder to customers’ bills. The costs eligible for recovery are prudently incurred air emissions credits associated with complying with federal, state, and local air emission regulations that apply to the generation of electricity reduced by the sale of such allowances. Also eligible for recovery are variable emission mitigation costs, which are the cost of reagents such as ammonia and limestone that are used to reduce air emissions. These variable emission mitigation costs were historically recovered through the Fuel Adjustment Clause.

Cleco Power currently has environmental adjustment clause filings for 2010 through 2012 subject to audit. Management is not able to predict or give a reasonable estimate of the possible range of the disallowance, if any, related to these filings. However, if a disallowance of environmental costs is ordered resulting in a refund, any such refund could have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows. The most recent environmental audit completed by the LPSC was for the period October 2009 through October 2010 and resulted in no disallowance of costs to be refunded to customers.

ITEM 4.MINE SAFETY DISCLOSURES

The information concerning mine safety violations or other regulatory matters required by Section 1503(a) of the Dodd-Frank Act and Item 104 of Regulation S-K is included in Exhibit 95 to this Combined Quarterly Report on Form 10-Q.

ITEM 5.OTHER INFORMATION

On October 30, 2012, Cleco Power announced Evangeline as the winning bidder in Cleco Power's 2012 Long-Term RFP, subject to further due diligence, the completion of definitive agreements, and regulatory approvals from the LPSC and FERC. The transaction is a transfer of ownership and control

of Coughlin Power Station from Evangeline to Cleco Power.  The transaction is expected to be closed in the third quarter of 2013, after the completion of regulatory reviews.

61

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

ITEM 6.   EXHIBITS
CLECO CORPORATION
12(a)	Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Stock Dividends for the three-, nine-, and twelve-month periods ended September 30, 2012, for Cleco Corporation
31.1	CEO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
31.2	CFO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
32.1	CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
32.2	CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
95	Mine Safety Disclosures
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase
CLECO POWER
12(b)	Computation of Ratios of Earnings to Fixed Charges for the three-, nine-, and twelve-month periods ended September 30, 2012, for Cleco Power
31.3	CEO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
31.4	CFO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
32.3	CEO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
32.4	CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
95	Mine Safety Disclosures
101.INS	XBRL Instance Document
101.SCH	XBRL Taxonomy Extension Schema
101.CAL	XBRL Taxonomy Extension Calculation Linkbase
101.DEF	XBRL Taxonomy Extension Definition Linkbase
101.LAB	XBRL Taxonomy Extension Label Linkbase
101.PRE	XBRL Taxonomy Extension Presentation Linkbase

62

CLECO CORPORATION
CLECO POWER	2012 3RD QUARTER FORM 10-Q

SIGNATURES

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

CLECO CORPORATION
(Registrant)
By:	/s/ Terry L. Taylor
	Terry L. Taylor
	Controller & Chief Accounting Officer

Date: October 30, 2012

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

CLECO POWER LLC
(Registrant)
By:	/s/ Terry L. Taylor
	Terry L. Taylor
	Controller & Chief Accounting Officer

Date: October 30, 2012

63

EX-12.A

CLECO CORPORATION EXHIBIT 12(a)

Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Stock Dividends
	FOR THE THREE MONTHS ENDED			FOR THE NINE MONTHS ENDED			FOR THE TWELVE MONTHS ENDED
(THOUSANDS, EXCEPT RATIOS)	SEPT. 30, 2012
Earnings from continuing operations	$	63,818		$	140,536		$	171,179
Income taxes	20,179			54,110			83,555
Earnings from continuing operations before income taxes	$	83,997		$	194,646		$	254,734
Fixed charges:
Interest	$	21,851		$	62,312		$	54,548
Amortization of debt expense, premium, net	759			2,359			3,200
Portion of rentals representative of an interest factor	126			368			498
Interest of capitalized lease	399			1,230			1,662
Total fixed charges	$	23,135		$	66,269		$	59,908
Earnings from continuing operations before income taxes	$	83,997		$	194,646		$	254,734
Plus:  total fixed charges from above	23,135			66,269			59,908
Plus:  amortization of capitalized interest	128			384			511
Earnings from continuing operations before income taxes and fixed charges	$	107,260		$	261,299		$	315,153
Ratio of earnings to fixed charges	4.64		X	3.94		X	5.26		X

EX-12.B

CLECO POWER EXHIBIT 12(b)

Computation of Ratios of Earnings to Fixed Charges
	FOR THE THREE MONTHS ENDED			FOR THE NINE MONTHS ENDED			FOR THE TWELVE MONTHS ENDED
(THOUSANDS, EXCEPT RATIOS)	SEPT. 30, 2012
Earnings from continuing operations	$	57,783		$	121,873		$	145,151
Income taxes	19,740			54,748			62,222
Earnings from continuing operations before income taxes	$	77,523		$	176,621		$	207,373
Fixed charges:
Interest	$	21,931		$	60,612		$	83,516
Amortization of debt expense, premium, net	675			2,107			2,694
Portion of rentals representative of an interest factor	126			368			498
Interest of capitalized lease	399			1,230			1,662
Total fixed charges	$	23,131		$	64,317		$	88,370
Earnings from continuing operations before income taxes	$	77,523		$	176,621		$	207,373
Plus:  total fixed charges from above	23,131			64,317			88,370
Earnings from continuing operations before income taxes and fixed charges	$	100,654		$	240,938		$	295,743
Ratio of earnings to fixed charges	4.35		X	3.75		X	3.35		X

EX-31.1

CLECO CORPORATION	EXHIBIT 31.1
Certification

I, Bruce A. Williamson, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Cleco Corporation;

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

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

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

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

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

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

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

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

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

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

Date:  October 30, 2012

/s/ Bruce A. Williamson

Bruce A. Williamson

President and Chief Executive Officer

EX-31.2

CLECO CORPORATION	EXHIBIT 31.2
Certification

I, Darren J. Olagues, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Cleco Corporation;

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

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

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

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

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

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

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

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

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

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

Date:  October 30, 2012

/s/  Darren J. Olagues

Darren J. Olagues

Senior Vice President and Chief Financial Officer 

EX-31.3

CLECO POWER LLC	EXHIBIT 31.3
Certification

I, Bruce A. Williamson, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Cleco Power LLC;

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

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

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

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

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

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

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

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

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

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

Date:  October 30, 2012

/s/ Bruce A. Williamson

Bruce A. Williamson

Chief Executive Officer

EX-31.4

CLECO POWER LLC	EXHIBIT 31.4
Certification

I, Darren J. Olagues, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Cleco Power LLC;

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

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

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

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

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

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

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

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

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

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

Date:  October 30, 2012

/s/  Darren J. Olagues

Darren J. Olagues

Senior Vice President and Chief Financial Officer

EX-32.1

CLECO CORPORATION EXHIBIT 32.1

Cleco Corporation

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Corporation (the “Company”) on Form 10-Q for the quarter ended September 30, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Bruce A. Williamson, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date: October 30, 2012

/s/  Bruce A. Williamson

Bruce A. Williamson

President and Chief Executive Officer

EX-32.2

CLECO CORPORATION EXHIBIT 32.2

Cleco Corporation

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Corporation (the “Company”) on Form 10-Q for the quarter ended September 30, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Darren J. Olagues, Senior Vice President and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:  October 30, 2012

/s/  Darren J. Olagues

Darren J. Olagues

Senior Vice President and Chief Financial Officer 

EX-32.3

CLECO POWER LLC	EXHIBIT 32.3
Cleco Power LLC
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Power LLC (the “Company”) on Form 10-Q for the quarter ended September 30, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Bruce A. Williamson, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date:  October 30, 2012

/s/  Bruce A. Williamson

Bruce A. Williamson

Chief Executive Officer

EX-32.4

CLECO POWER LLC	EXHIBIT 32.4
Cleco Power LLC
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the Quarterly Report of Cleco Power LLC (the “Company”) on Form 10-Q for the quarter ended September 30, 2012, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Darren J. Olagues, Senior Vice President and Chief Financial Officer of the Company, certify, pursuant to 18 U.S.C. §1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

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

Date: October 30, 2012

/s/  Darren J. Olagues

Darren J. Olagues

Senior Vice President and Chief Financial Officer

EX-95

CLECO CORPORATION
CLECO POWER	EXHIBIT 95

MINE SAFETY DISCLOSURES

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

Under Section 1503 of the Dodd-Frank Act, public reporting companies that meet the definition of an “operator” of a mine under the Federal Mine Safety and Health Act of 1977 (Mine Act) as administered by the Mine Safety and Health Administration (MSHA) are required to report notices of violations and proposed assessments of violations of MSHA regulations promulgated in support of the Mine Act.  The MSHA defines an operator as any owner, lessee, or other person who operates, controls, or supervises a coal or other mine or any independent contractor performing services or construction at such mine.  Cleco Power might meet the definition of an “operator” under the MSHA through its two representatives on the executive committee.  Therefore, Cleco Power has chosen to include the disclosures required by Section 1503 of the Dodd-Frank Act.  During the third quarter of 2012, DHLC received five notices of violation by MSHA, with three of those being classified as Significant and Substantial. MSHA assessed penalties on all five of the citations during the third quarter, and the total of all penalties was immaterial. Two additional citations, one being Significant and Substantial, were issued in the second quarter but was not assessed by MSHA until the third quarter. The total for these two penalties was also immaterial. The MSHA definition of control is not the same as the definition of control pursuant to accounting pronouncements relating to consolidation and equity method investments.  Management has determined that its relationship with DHLC does not meet the definition of control under accounting pronouncements; therefore, Cleco Power has not included any financial information about DHLC in its periodic reports.

XML

Summary of Significant Accounting Policies, Property, Plant and Equipment (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Accounting Policies [Abstract]
Regulated utility plants	$ 3,815,608	$ 3,759,541
Other	267,028	264,114
Property, plant and equipment	4,082,636	4,023,655
Accumulated depreciation	(1,291,862)	(1,230,783)
Net property, plant, and equipment	$ 2,790,774	$ 2,792,872

XML

Pension Plan and Employee Benefits, Pension Plan and Other Benefits Plan (Details) (USD $)	3 Months Ended		9 Months Ended		12 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
General information			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 10 years of employment with Cleco.
Components of periodic benefit costs
Service cost	$ 2,078,000	$ 2,097,000	$ 6,234,000	$ 6,292,000
Interest cost	4,563,000	4,407,000	13,690,000	13,222,000
Expected return on plan assets	(5,201,000)	(6,161,000)	(15,604,000)	(18,484,000)
Transition obligation	0	0	0	0
Prior period service cost	(18,000)	(18,000)	(53,000)	(54,000)
Net loss	2,087,000	1,389,000	6,259,000	4,167,000
Net periodic benefit cost	3,509,000	1,714,000	10,526,000	5,143,000
Discretionary contributions to the pension plan			0		60,000,000
Pension Benefits [Member] | Other Subsidiaries [Member]
Components of periodic benefit costs
Net periodic benefit cost	500,000	500,000	1,600,000	1,600,000
Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
General information			Cleco’s retirees and their dependents are eligible to receive medical, dental, vision, and life insurance benefits (other benefits).
Current portion of other benefits liability	3,100,000		3,100,000		3,100,000
Components of periodic benefit costs
Service cost	303,000	390,000	1,096,000	1,149,000
Interest cost	334,000	443,000	1,287,000	1,364,000
Expected return on plan assets	0	0	0	0
Transition obligation	5,000	5,000	15,000	15,000
Prior period service cost	0	(51,000)	0	(154,000)
Net loss	112,000	246,000	512,000	758,000
Net periodic benefit cost	754,000	1,033,000	2,910,000	3,132,000
Other Benefits [Member] | Cleco Power [Member]
Defined Benefit Plan Disclosure [Line Items]
Current portion of other benefits liability	2,900,000		2,900,000		2,900,000
Components of periodic benefit costs
Net periodic benefit cost	700,000	900,000	2,500,000	2,700,000
Prior Plan Year [Member] | Pension Benefits [Member]
Components of periodic benefit costs
Contributions designated for prior plan year					40,100,000
Current Plan Year [Member] | Pension Benefits [Member]
Components of periodic benefit costs
Contributions designated for current plan year					$ 19,900,000

XML

Fair Value Accounting, Restricted Investments (Details) (USD $)										3 Months Ended	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2012 Municipal Bonds [Member]	Sep. 30, 2012 Restricted Storm Reserve [Member] Municipal Bonds [Member]	Jul. 02, 2012 Cleco Power [Member]	Sep. 30, 2007 Cleco Power [Member]	Sep. 30, 2012 Estimated Fair Value [Member] Measured On A Recurring Basis [Member]	Dec. 31, 2011 Estimated Fair Value [Member] Measured On A Recurring Basis [Member]	Sep. 30, 2012 Estimated Fair Value [Member] Measured On A Recurring Basis [Member] Cleco Power [Member]	Dec. 31, 2011 Estimated Fair Value [Member] Measured On A Recurring Basis [Member] Cleco Power [Member]	Sep. 30, 2012 Maximum [Member] Restricted Storm Reserve [Member] Municipal Bonds [Member]	Sep. 30, 2012 Maximum [Member] Restricted Storm Reserve [Member] Municipal Bonds [Member]
Schedule of Available-for-sale Securities [Line Items]
LPSC authorized storm reserve funding					$ 50,000,000
Available-for-sale Securities, Change in Net Unrealized Gain (Loss), Net of tax										100,000	100,000
Available-for-sale Securities, Continuous Unrealized Loss Position [Abstract]
Available-for-sale Securities, Continuous Unrealized Loss Position, Aggregate Losses	9,000
Available-for-sale Securities, Continuous Unrealized Loss Position, Less than Twelve Months, Fair Value	3,381,000
Available-for-sale Securities, Continuous Unrealized Loss Position, 12 Months or Longer, Aggregate Losses	0
Available-for-sale Securities, Continuous Unrealized Loss Position, Twelve Months or Longer, Fair Value	0
Available-for-sale Securities, Debt Maturities, Next Twelve Months, Fair Value		1,022,000
Available-for-sale Securities, Debt Maturities, Year Two Through Five, Fair Value		3,448,000
Available-for-sale Securities, Fair Value Disclosure		4,470,000				4,470,000	0	4,470,000	0
Available-for-sale Securities, Amortized Cost Basis		4,477,000
Available-for-sale Securities, Gross Unrealized Gains			2,000
Available-for-sale Securities, Gross Unrealized Losses			9,000
Amount of restricted cash and cash equivalents transfered to an investment manager				$ 13,000,000

XML

Affiliate Transactions (Details) (Cleco Power [Member], USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Related Party Transaction [Line Items]
Accounts payable - affiliate	$ 10,069	$ 9,311
Accounts receivable - affiliate	3,373	2,405
Cleco Corporation [Member]
Related Party Transaction [Line Items]
Accounts payable - affiliate	800
Accounts receivable - affiliate	1,300
Support Group [Member]
Related Party Transaction [Line Items]
Accounts payable - affiliate	5,700
Accounts receivable - affiliate	2,000
Evangeline [Member]
Related Party Transaction [Line Items]
Accounts payable - affiliate	3,500
Maximum [Member] | Others [Member]
Related Party Transaction [Line Items]
Accounts payable - affiliate	100
Accounts receivable - affiliate	$ 100

XML

Pension Plan and Employee Benefits, SERP (Details) (SERP Benefits [Member], USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Defined Benefit Plan Disclosure [Line Items]
General information			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 and the average of the three highest 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.
Components of periodic benefit costs
Service cost	$ 372,000	$ 392,000	$ 1,115,000	$ 1,175,000
Interest cost	632,000	526,000	1,895,000	1,578,000
Prior period service cost	13,000	13,000	40,000	40,000
Net loss	441,000	234,000	1,324,000	705,000
Net periodic benefit cost	1,458,000	1,165,000	4,374,000	3,498,000
Curent portion of SERP liability	2,500,000		2,500,000		2,200,000
Cleco Power [Member]
Components of periodic benefit costs
Net periodic benefit cost	400,000	300,000	1,100,000	900,000
Curent portion of SERP liability	$ 800,000		$ 800,000		$ 800,000

XML

Fair Value Accounting, Carrying Value and Estimated Fair Value (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Carrying Value [Member]
Financial instruments not marked-to-market [Abstract]
Cash and cash equivalents	$ 68,364	$ 93,576
Restricted cash and cash equivalents	16,726	35,828
Long-term debt, excluding debt issuance costs	1,320,198	1,354,567
Estimated Fair Value [Member]
Financial instruments not marked-to-market [Abstract]
Cash and cash equivalents	68,364	93,576
Restricted cash and cash equivalents	16,726	35,828
Long-term debt, excluding debt issuance costs	1,553,694	1,542,867
Cleco Power [Member] | Carrying Value [Member]
Financial instruments not marked-to-market [Abstract]
Cash and cash equivalents	50,578	67,458
Restricted cash and cash equivalents	16,629	35,731
Long-term debt, excluding debt issuance costs	1,320,198	1,344,567
Cleco Power [Member] | Estimated Fair Value [Member]
Financial instruments not marked-to-market [Abstract]
Cash and cash equivalents	50,578	67,458
Restricted cash and cash equivalents	16,629	35,731
Long-term debt, excluding debt issuance costs	$ 1,553,694	$ 1,532,867

XML

Fair Value Accounting (Tables)

9 Months Ended

Sep. 30, 2012

Fair Value [Line Items]

Fair Value By Balance Sheet Grouping

The following tables summarize the carrying value and estimated market value of Cleco and Cleco Power’s financial instruments subject to fair value accounting.

Cleco
	AT SEPT. 30, 2012				AT DEC. 31, 2011
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market
Cash and cash equivalents	$	68,364	$	68,364	$	93,576	$	93,576
Restricted cash and cash equivalents	$	16,726	$	16,726	$	35,828	$	35,828
Long-term debt, excluding debt issuance costs	$	1,320,198	$	1,553,694	$	1,354,567	$	1,542,867

Schedule of Available-for-sale Securities Reconciliation

The following table provides a reconciliation of Cleco Power's available-for-sale securities from cost basis to fair value at September 30, 2012.

	AT SEPT. 30, 2012
(THOUSANDS)	AMORTIZED COST		TOTAL UNREALIZED GAINS (1)		TOTAL UNREALIZED LOSSES (1)		FAIR VALUE
Municipal bonds	$	4,477	$	2	$	9	$	4,470
(1)  Unrealized gains and losses are recorded to the restricted storm reserve.

Available-for-sale Securities, Continuous Unrealized Loss Position, Fair Value

The following table summarizes the securities that were in an unrealized loss position at September 30, 2012, but for which no other-than-temporary impairment was recognized:

			LESS THAN 12 MONTHS		12 MONTHS OR LONGER
(THOUSANDS)	AGGREGATE UNREALIZED LOSS		AGGREGATE RELATED FAIR VALUE		AGGREGATE UNREALIZED LOSS		AGGREGATE RELATED FAIR VALUE
Municipal bonds	$	9	$	3,381	$	—	$	—

Available-for-sale Securities

At September 30, 2012, the fair value of Cleco Power's available-for-sale securities by contractual maturity was:

(THOUSANDS)	AT SEPT. 30, 2012
One year or less	$	1,022
Over one year through five years	3,448
Total fair value	$	4,470

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 SEPT. 30, 2012		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2011		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Institutional money market funds	$	74,712	$	—	$	74,712	$	—	$	118,951	$	—	$	118,951	$	—
Municipal bonds	$	4,470	$	—	$	4,470	$	—	$	—	$	—	$	—	$	—
Total assets	$	79,182	$	—	$	79,182	$	—	$	118,951	$	—	$	118,951	$	—
Liability Description
Energy market derivatives	$	—	$	—	$	—	$	—	$	5,336	$	—	$	5,336	$	—
Interest rate derivatives	4,063		—		4,063		—		3,330		—		3,330		—
Long-term debt	1,553,694		—		1,553,694		—		1,542,867		—		1,542,867		—
Total liabilities	$	1,557,757	$	—	$	1,557,757	$	—	$	1,551,533	$	—	$	1,551,533	$	—

Fair Values of Derivative Instruments

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 as of September 30, 2012 and December 31, 2011.

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
	LIABILITY DERIVATIVES
(THOUSANDS) FAIR VALUE	BALANCE SHEET  LINE ITEM	AT SEPT. 30, 2012		AT DEC. 31, 2011
Commodity contracts
Fuel cost hedges:
Current	Energy risk management liability, net	$	—	$	(5,336	)
Total		$	—	$	(5,336	)

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 and nine months ended September 30, 2012 and 2011.

	FOR THE THREE MONTHS ENDED SEPT. 30,								FOR THE NINE MONTHS ENDED SEPT. 30,
		2012			2011				2012			2011
(THOUSANDS)	LOSS IN  INCOME OF DERIVATIVES  LINE ITEM	AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			LOSS IN  INCOME OF DERIVATIVES  LINE ITEM	AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES
Commodity contracts
Fuel cost hedges(1)	Fuel used for electric generation	$	(595	)	$	(5,678	)	Fuel used for electric generation	$	(8,210	)	$	(14,675	)
Total		$	(595	)	$	(5,678	)		$	(8,210	)	$	(14,675	)
(1)In accordance with the authoritative guidance for regulated operations, no unrealized gains or losses and $0.1 million of deferred losses associated with fuel cost hedges are reported in Accumulated Deferred Fuel on the balance sheet as of September 30, 2012, compared to $5.3 million of unrealized losses and $1.2 million of deferred losses associated with fuel cost hedges as of December 31, 2011. As gains and losses are realized in future periods, they will be recorded as Fuel Used for Electric Generation on the income statement.

The following tables present the effect of derivatives designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2012 and 2011.

						FOR THE THREE MONTHS ENDED SEPT. 30,
	2012					2011
(THOUSANDS)	AMOUNT OF GAIN RECOGNIZED IN OCI		AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)			AMOUNT OF LOSS RECOGNIZED IN OCI			AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)
Interest rate derivatives	$	802	$	17	*	$	(29,962	)	$	89	*
* The gain (loss) reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.

							FOR THE NINE MONTHS ENDED SEPT. 30,
	2012						2011
(THOUSANDS)	AMOUNT OF LOSS  RECOGNIZED IN OCI			AMOUNT OF LOSS RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)			AMOUNT OF LOSS RECOGNIZED IN OCI			AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)
Interest rate derivatives(1)	$	(733	)	$	(39	)*	$	(29,962	)	$	267	*
* The (loss) gain reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.
(1) During the nine months ended September 30, 2012, Cleco recorded $2.6 million of ineffectiveness related to the interest rate derivatives as a regulatory asset.

Cleco Power [Member]

Fair Value [Line Items]

Fair Value By Balance Sheet Grouping

Cleco Power
	AT SEPT. 30, 2012				AT DEC. 31, 2011
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market
Cash and cash equivalents	$	50,578	$	50,578	$	67,458	$	67,458
Restricted cash and cash equivalents	$	16,629	$	16,629	$	35,731	$	35,731
Long-term debt, excluding debt issuance costs	$	1,320,198	$	1,553,694	$	1,344,567	$	1,532,867

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

Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2012		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2011		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Institutional money market funds	$	61,115	$	—	$	61,115	$	—	$	99,955	$	—	$	99,955	$	—
Municipal bonds	$	4,470	$	—	$	4,470	$	—	$	—	$	—	$	—	$	—
Total assets	$	65,585	$	—	$	65,585	$	—	$	99,955	$	—	$	99,955	$	—
Liability Description
Energy market derivatives	$	—	$	—	$	—	$	—	$	5,336	$	—	$	5,336	$	—
Interest rate derivatives	4,063		—		4,063		—		3,330		—		3,330		—
Long-term debt	1,553,694		—		1,553,694		—		1,532,867		—		1,532,867		—
Total liabilities	$	1,557,757	$	—	$	1,557,757	$	—	$	1,541,533	$	—	$	1,541,533	$	—

XML

Income Taxes, Effective Tax Rate Reconciliation (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Effective Income Tax Rate [Line Items]
Effective Rate (in hundredths)	24.00%	27.30%	27.80%	30.80%
Cleco Power [Member]
Effective Income Tax Rate [Line Items]
Effective Rate (in hundredths)	25.50%	37.00%	31.00%	34.10%

XML

Acadia Unit 2 Transaction (Details) (USD $)			6 Months Ended
	Sep. 30, 2012	Dec. 31, 2011	Jun. 30, 2011 APH [Member] Acadia Unit 2 and Facilities [Member]	Apr. 29, 2011 APH [Member] Acadia Unit 2 and Facilities [Member]	Apr. 29, 2011 Acadia Power Partners [Member] Acadia Unit 2 and Facilities [Member]	Apr. 29, 2011 Acadia Power Partners [Member] APH [Member]	Apr. 29, 2011 Cajun [Member] APH [Member]
Significant Acquisitions and Disposals [Line Items]
Proceeds from plant disposition					$ 298,800,000
Indemnification liability representing risk of payment	10,350,000	29,357,000		10,900,000
Recognized gain on transaction				62,000,000
Third parties' share of entity's liabilities (in hundredths)				50.00%
Net adjustment to equity income				26,200,000
Impairment of investment			45,900,000
Accumulated Capitalized Interest Costs				$ 19,700,000
Ownership interest received (in hundredths)						100.00%
Ownership interest exchanged (in hundredths)							50.00%

XML

Regulatory Assets and Liabilities (Policies)

9 Months Ended

Sep. 30, 2012

Regulatory Assets and Liabilities Disclosure [Abstract]

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.

XML

Fair Value Accounting, Fair Value of Financial Assets and Liabilities Measured on a Recurring Basis (Details) (USD $)	Sep. 30, 2012	Dec. 31, 2011
Liability Description
Institutional money market funds cash and cash equivalents	$ 58,500,000
Institutional money market funds current restricted cash	3,400,000
Institutional money market funds non-current restricted cash	12,800,000
Measured On A Recurring Basis [Member] | Estimated Fair Value [Member]
Asset Description
Institutional money market funds	74,712,000	118,951,000
Available-for-sale Securities, Fair Value Disclosure	4,470,000	0
Total Assets	79,182,000	118,951,000
Liability Description
Long-term debt, excluding debt issuance costs	1,553,694,000	1,542,867,000
Total Liabilities	1,557,757,000	1,551,533,000
Measured On A Recurring Basis [Member] | Estimated Fair Value [Member] | Energy Market Derivatives [Member]
Liability Description
Derivative liabilities	0	5,336,000
Measured On A Recurring Basis [Member] | Estimated Fair Value [Member] | Interest Rate Derivatives [Member]
Liability Description
Derivative liabilities	4,063,000	3,330,000
Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]
Asset Description
Institutional money market funds	0	0
Available-for-sale Securities, Fair Value Disclosure	0	0
Total Assets	0	0
Liability Description
Long-term debt, excluding debt issuance costs	0	0
Total Liabilities	0	0
Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Energy Market Derivatives [Member]
Liability Description
Derivative liabilities	0	0
Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Interest Rate Derivatives [Member]
Liability Description
Derivative liabilities	0	0
Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member]
Asset Description
Institutional money market funds	74,712,000	118,951,000
Available-for-sale Securities, Fair Value Disclosure	4,470,000	0
Total Assets	79,182,000	118,951,000
Liability Description
Long-term debt, excluding debt issuance costs	1,553,694,000	1,542,867,000
Total Liabilities	1,557,757,000	1,551,533,000
Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Energy Market Derivatives [Member]
Liability Description
Derivative liabilities	0	5,336,000
Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Derivatives [Member]
Liability Description
Derivative liabilities	4,063,000	3,330,000
Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member]
Asset Description
Institutional money market funds	0	0
Available-for-sale Securities, Fair Value Disclosure	0	0
Total Assets	0	0
Liability Description
Long-term debt, excluding debt issuance costs	0	0
Total Liabilities	0	0
Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member] | Energy Market Derivatives [Member]
Liability Description
Derivative liabilities	0	0
Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member] | Interest Rate Derivatives [Member]
Liability Description
Derivative liabilities	0	0
Cleco Power [Member]
Liability Description
Institutional money market funds cash and cash equivalents	45,000,000
Institutional money market funds current restricted cash	3,400,000
Institutional money market funds non-current restricted cash	12,700,000
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Estimated Fair Value [Member]
Asset Description
Institutional money market funds	61,115,000	99,955,000
Available-for-sale Securities, Fair Value Disclosure	4,470,000	0
Total Assets	65,585,000	99,955,000
Liability Description
Long-term debt, excluding debt issuance costs	1,553,694,000	1,532,867,000
Total Liabilities	1,557,757,000	1,541,533,000
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Estimated Fair Value [Member] | Energy Market Derivatives [Member]
Liability Description
Derivative liabilities	0	5,336,000
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Estimated Fair Value [Member] | Interest Rate Derivatives [Member]
Liability Description
Derivative liabilities	4,063,000	3,330,000
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member]
Asset Description
Institutional money market funds	0	0
Available-for-sale Securities, Fair Value Disclosure	0	0
Total Assets	0	0
Liability Description
Long-term debt, excluding debt issuance costs	0	0
Total Liabilities	0	0
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Energy Market Derivatives [Member]
Liability Description
Derivative liabilities	0	0
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Quoted Prices in Active Markets for Identical Assets (Level 1) [Member] | Interest Rate Derivatives [Member]
Liability Description
Derivative liabilities	0	0
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member]
Asset Description
Institutional money market funds	61,115,000	99,955,000
Available-for-sale Securities, Fair Value Disclosure	4,470,000	0
Total Assets	65,585,000	99,955,000
Liability Description
Long-term debt, excluding debt issuance costs	1,553,694,000	1,532,867,000
Total Liabilities	1,557,757,000	1,541,533,000
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Energy Market Derivatives [Member]
Liability Description
Derivative liabilities	0	5,336,000
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Significant Other Observable Inputs (Level 2) [Member] | Interest Rate Derivatives [Member]
Liability Description
Derivative liabilities	4,063,000	3,330,000
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member]
Asset Description
Institutional money market funds	0	0
Available-for-sale Securities, Fair Value Disclosure	0	0
Total Assets	0	0
Liability Description
Long-term debt, excluding debt issuance costs	0	0
Total Liabilities	0	0
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member] | Energy Market Derivatives [Member]
Liability Description
Derivative liabilities	0	0
Cleco Power [Member] | Measured On A Recurring Basis [Member] | Significant Unobservable Inputs (Level 3) [Member] | Interest Rate Derivatives [Member]
Liability Description
Derivative liabilities	$ 0	$ 0

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Summary of Significant Accounting Policies, Earnings Per Average Common Share (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
INCOME
Net income	$ 63,818	$ 65,842	$ 140,536	$ 165,205
Deduct: non-participating stock dividends (4.5% preferred stock)			0	26
Deduct: non-participating stock redemption costs (4.5% preferred stock)			0	112
Basic net income applicable to common stock	63,818	65,842	140,536	165,067
Diluted net income applicable to common stock	$ 63,818	$ 65,842	$ 140,536	$ 165,067
SHARES
Average number of basic common shares outstanding (in shares)	60,346,476	60,467,595	60,375,538	60,549,860
Effect of dilutive securities
Add: stock option grants (in shares)	1,536	20,441	4,518	20,965
Add: restricted stock (LTICP) (in shares)	251,191	385,275	246,415	259,426
Average number of diluted common shares outstanding (in shares)	60,599,203	60,873,311	60,626,471	60,830,251
PER SHARE AMOUNT
Net income applicable to common stock (in dollars per share)	$ 1.06	$ 1.09	$ 2.33	$ 2.73
Diluted net income per average common share (in dollars per share)	$ 1.05	$ 1.08	$ 2.32	$ 2.71
Cumulative Preferred Stock, 100 Par Value [Member]
Dividends Payable [Line Items]
Preferred stock, dividend rate			4.50%

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Variable Interest Entities (Tables)

9 Months Ended

Sep. 30, 2012

Variable Interest Entities [Abstract]

Equity Income Loss from Investments Accounted for Using the Equity Method

The following table presents the equity income (loss) from each investment accounted for using the equity method.  

	FOR THE THREE MONTHS ENDED SEPT. 30,					FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011			2012		2011
Cajun	$	—	$	—		$	—	$	62,053
Subsidiaries less than 100% owned by Cleco Innovations	—		(1		)	1		(2		)
Total equity (loss) income	$	—	$	(1	)	$	1	$	62,051

Equity Method Investments - Summarized Financial Information

The following table contains summarized financial information for Cajun prior to the disposition of Acadia Unit 2.

(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2011*
Operating revenue		$	5,227
Operating expenses		5,914
Gain on sale of assets		71,422
Other income		929
Income before taxes		$	71,664
*The 2011 income statement includes only activity through the April 29, 2011, reconsolidation.

The following tables contain summarized financial information for Oxbow.

(THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
Current assets	$	1,753	$	1,711
Property, plant, and equipment, net	23,119		23,339
Other assets	4,247		4,128
Total assets	$	29,119	$	29,178
Current liabilities	$	24	$	40
Other liabilities	30		73
Partners’ capital	29,065		29,065
Total liabilities and partners’ capital	$	29,119	$	29,178

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
Operating revenue	$	450	$	382	$	1,125	$	880
Operating expenses	450		382		1,125		880
Income before taxes	$	—	$	—	$	—	$	—

Components of Equity Investments

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

INCEPTION TO DATE (THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
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 SEPT. 30, 2012		AT DEC. 31, 2011
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

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Fair Value Accounting, Effect of Derivatives on Consolidated Statements of Income (Details) (USD $)		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended	12 Months Ended
	Dec. 31, 2011 MMBTU	Sep. 30, 2012 Derivatives Not Designated As Hedging Instruments [Member]	Sep. 30, 2011 Derivatives Not Designated As Hedging Instruments [Member]	Sep. 30, 2012 Derivatives Not Designated As Hedging Instruments [Member]	Sep. 30, 2011 Derivatives Not Designated As Hedging Instruments [Member]	Sep. 30, 2012 Derivatives Not Designated As Hedging Instruments [Member] Fuel Cost Hedges [Member] Fuel Used For Electric Generation [Member]	Sep. 30, 2011 Derivatives Not Designated As Hedging Instruments [Member] Fuel Cost Hedges [Member] Fuel Used For Electric Generation [Member]	Sep. 30, 2012 Derivatives Not Designated As Hedging Instruments [Member] Fuel Cost Hedges [Member] Fuel Used For Electric Generation [Member]	Sep. 30, 2011 Derivatives Not Designated As Hedging Instruments [Member] Fuel Cost Hedges [Member] Fuel Used For Electric Generation [Member]	Sep. 30, 2012 Derivatives Designated as Hedging Instruments [Member] Interest Rate Derivatives [Member]	Sep. 30, 2011 Derivatives Designated as Hedging Instruments [Member] Interest Rate Derivatives [Member]	Sep. 30, 2012 Derivatives Designated as Hedging Instruments [Member] Interest Rate Derivatives [Member]	Sep. 30, 2011 Derivatives Designated as Hedging Instruments [Member] Interest Rate Derivatives [Member]	Sep. 30, 2012 Cleco Power [Member]	Dec. 31, 2011 Cleco Power [Member]	Sep. 30, 2012 AccumulatedDeferredFuel [Member] Derivatives Not Designated As Hedging Instruments [Member] Fuel Cost Hedges [Member]	Dec. 31, 2011 AccumulatedDeferredFuel [Member] Derivatives Not Designated As Hedging Instruments [Member] Fuel Cost Hedges [Member]	Sep. 30, 2012 Maximum [Member] AccumulatedDeferredFuel [Member] Derivatives Not Designated As Hedging Instruments [Member] Fuel Cost Hedges [Member]
Derivative, gain (loss) recognized in income [Abstract]
Amount of loss recognized in income on derivatives		$ (595,000)	$ (5,678,000)	$ (8,210,000)	$ (14,675,000)	$ (595,000)	$ (5,678,000)	$ (8,210,000)	$ (14,675,000)
Unrealized gains (losses)																	(5,300,000)	0
Deferred gains (losses)																(100,000)	(1,200,000)
Amount of (loss) gain recognized in OCI										802,000	(29,962,000)	(733,000)	(29,962,000)
Amount of (loss) gain reclassified from accumulated OCI into income (effective portion)										17,000	89,000	(39,000)	267,000
Cash flow hedge gain (loss) expected to be reclassed from accumulated OCI over the next 12 months												(400,000)
Amount of ineffectiveness related to the interest rate derivative												$ 2,600,000
Natural gas requirements hedged [Abstract]
Millions MMBtus hedged for natural gas fuel costs	2,200,000
Estimated natural gas requirements covered (in hundredths)	3.00%
Estimated natural gas requirements period (in years)														0	2 years

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Off-Balance Sheet Commitments (Details) (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Jan. 31, 2006
Guarantor Obligations [Line Items]
FACE AMOUNT	$ 4,225
REDUCTIONS	0
NET AMOUNT	4,225
Cleco Corporation [Member] | Guarantee Issued to Entergy Mississippi on behalf of Attala [Member]
Guarantor Obligations [Line Items]
FACE AMOUNT	500
REDUCTIONS	0
NET AMOUNT	500	500
Cleco Power [Member] | Obligations Under Standby Letter of Credit Issued to the Louisiana Department of Labor [Member]
Guarantor Obligations [Line Items]
FACE AMOUNT	3,725
REDUCTIONS	0
NET AMOUNT	$ 3,725
Percentage of average losses on which letter of credit is based (in hundredths)	110.00%

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Income Taxes, Income Tax Examination (Details) (USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Feb. 28, 2011	Dec. 31, 2010
Internal Revenue Service (IRS) [Member]
Summary of income tax examinations [Abstract]
Deposits with IRS	$ 60.4	$ 8.2	$ 52.2
Amounts deposited with IRS- remaining amount to offset tax and interest liabilities	43.5
Maximum decrease in unrecognized tax benefits as a result of settlement with the IRS	$ 0.6
Minimum [Member] | Internal Revenue Service (IRS) [Member]
Summary of income tax examinations [Abstract]
Income Tax Years That Are Subject To Examination	2001
Income tax years that are under examination	2001
Minimum [Member] | State and Local Jurisdiction [Member]
Summary of income tax examinations [Abstract]
Income Tax Years That Are Subject To Examination	2001
Maximum [Member] | Internal Revenue Service (IRS) [Member]
Summary of income tax examinations [Abstract]
Income Tax Years That Are Subject To Examination	2011
Income tax years that are under examination	2009
Maximum [Member] | State and Local Jurisdiction [Member]
Summary of income tax examinations [Abstract]
Income Tax Years That Are Subject To Examination	2011

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Fair Value Accounting, Concentration of Risk (Details) (USD $)	9 Months Ended
	Sep. 30, 2012
Established guidelines for short-term investments to mitigate potential credit risk [Abstract]
Percentage Of Investments In Securities	5.00%
Percentage Of Portfolio	50.00%
Minimum assets under management in money market funds	$ 15,000,000,000
Minimum existence of investments (in years)	2 years
Maximum Amount of Loss [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Concentrations of credit risk through short-term investments	74,700,000
Concentrations of credit risk through their short-term investments in cash	58,500,000
Concentrations of credit risk through their short-term investments in restricted cash	16,200,000
Cleco Power [Member] | Maximum Amount of Loss [Member]
Fair Value, Concentration of Risk, Financial Statement Captions [Line Items]
Concentrations of credit risk through short-term investments	61,100,000
Concentrations of credit risk through their short-term investments in cash	45,000,000
Concentrations of credit risk through their short-term investments in restricted cash	$ 16,100,000

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Recent Authoritative Guidance

9 Months Ended

Sep. 30, 2012

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

Recent Authoritative Guidance

Note 2 — Recent Authoritative Guidance

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

In April 2011, FASB issued guidance to improve the accounting for repurchase agreements and other similar agreements. Specifically, this guidance modifies the criteria for determining when these transactions would be accounted for as financings as opposed to sales or purchases with commitments to repurchase or resale. The adoption of this guidance was effective for the first period beginning on or after December 15, 2011. The adoption of this guidance did not have a material impact on the financial condition or results of operations of the Registrants.

In May 2011, FASB issued guidance on fair value measurements. This guidance results in a consistent definition of fair value and common requirements for measurement of and disclosure about fair value between GAAP and International Financial Reporting Standards. The adoption of this guidance is effective prospectively for interim and annual periods beginning after December 15, 2011. The adoption of this guidance did not have a material impact on the financial condition or results of operations of the Registrants.

In December 2011, FASB revised the disclosure requirements related to balance sheet offsetting. After the effective date, entities must disclose both the gross and net information about instruments and transactions eligible for offsetting on the balance sheet, including transactions under master netting agreements. The adoption of this revision is required for interim and annual periods beginning on or after January 1, 2013. The adoption of this revision will not have any effect on the financial condition or results of operations of the Registrants since it relates to disclosures.

In July 2012, FASB issued guidance on testing indefinite-lived intangible assets for impairment. This guidance is intended to reduce costs and complexity of testing indefinite-lived intangible assets other than goodwill for impairment. Entities are allowed to perform a “qualitative” assessment to determine whether further impairment testing of indefinite-lived intangible assets is necessary, similar in approach to the goodwill impairment test. The adoption of this guidance is effective for annual and interim impairment tests performed for fiscal years beginning after September 15, 2012. The adoption of this guidance will not have any impact on the financial condition or results of operations of the Registrants.

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Disclosures about Segments (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012 entity	Sep. 30, 2011	Sep. 30, 2012 entity	Sep. 30, 2011	Dec. 31, 2011
Segment Reporting Information [Line Items]
Number of transmission interconnection facility subsidiaries	2		2
Revenue
Electric operations	$ 282,894	$ 324,532	$ 720,776	$ 823,484
Tolling operations	0	9,133	0	16,137
Other operations	15,408	16,064	38,464	41,775
Electric customer credits	(930)	1,852	1,025	(3,405)
Affiliate revenue	0	0	0	202
Operating revenue, net	297,372	351,581	760,265	878,193
Depreciation	34,931	31,237	99,028	91,749
Interest charges	21,966	25,779	63,205	78,011
Interest income	132	509	163	794
Equity income (loss) from investees, before tax	0	(1)	1	62,051
Federal and state income tax expense	20,179	24,737	54,110	73,451
Net income	63,818	65,842	140,536	165,205
Additions to long-lived assets	66,375	80,368	168,018	158,033
Equity investment in investees	14,541		14,541		14,540
Total segment assets	4,106,893		4,106,893		4,050,202
Unallocated items:
Preferred dividends requirements			0	26
Preferred stock redemption costs			0	112
Net income applicable to common stock	63,818	65,842	140,536	165,067
Midstream [Member]
Revenue
Electric operations	0	0	0	0
Tolling operations	13,890	9,133	21,434	16,137
Other operations	1	1	2	8
Electric customer credits	0	0	0	0
Affiliate revenue	0	0	0	45
Operating revenue, net	13,891	9,134	21,436	16,190
Depreciation	1,499	1,457	4,491	4,370
Interest charges	(69)	752	244	1,963
Interest income	0	5	0	6
Equity income (loss) from investees, before tax		0	0	62,053
Federal and state income tax expense	2,489	444	7,278	21,296
Net income	3,429	5,946	11,053	39,274
Additions to long-lived assets	799	4,074	6,811	5,202
Equity investment in investees	0		0		0
Total segment assets	221,503		221,503		233,891
Reconciling Items [Member]
Revenue
Electric operations	0	0	0	0
Tolling operations	0	0	0	0
Other operations	502	500	1,496	1,511
Electric customer credits	0	0	0	0
Affiliate revenue	12,343	13,448	37,540	37,544
Operating revenue, net	12,845	13,948	39,036	39,055
Depreciation	233	241	689	728
Interest charges	(124)	(308)	1,320	1,891
Interest income	(194)	199	(379)	103
Equity income (loss) from investees, before tax		(1)	1	(2)
Federal and state income tax expense	(2,050)	(7,363)	(7,916)	(9,781)
Net income	2,606	6,063	7,610	6,374
Additions to long-lived assets	503	81	1,371	749
Equity investment in investees	9		9		8
Total segment assets	194,996		194,996		201,074
Eliminations [Member]
Revenue
Electric operations	0	0	0	0
Tolling operations	(13,890)	0	(21,434)	0
Other operations	0	(2)	(1)	(5)
Electric customer credits	0	0	0	0
Affiliate revenue	(12,686)	(13,795)	(38,570)	(38,428)
Operating revenue, net	(26,576)	(13,797)	(60,005)	(38,433)
Depreciation	0	0	1	1
Interest charges	197	29	388	128
Interest income	197	29	389	128
Equity income (loss) from investees, before tax		0	0	0
Federal and state income tax expense	0	0	0	1
Net income	0	0	0	0
Additions to long-lived assets	0	0	0	0
Equity investment in investees	0		0		0
Total segment assets	(149,737)		(149,737)		(111,234)
Unallocated Amount to Segment [Member]
Unallocated items:
Preferred dividends requirements				26
Preferred stock redemption costs				112
Cleco Power [Member]
Revenue
Electric operations	282,894	324,532	720,776	823,484
Tolling operations	0	0	0	0
Other operations	14,905	15,565	36,967	40,261
Electric customer credits	(930)	1,852	1,025	(3,405)
Affiliate revenue	343	347	1,030	1,041
Operating revenue, net	297,212	342,296	759,798	861,381
Depreciation	33,199	29,539	93,847	86,650
Interest charges	21,962	25,306	61,253	74,029
Interest income	129	276	153	557
Equity income (loss) from investees, before tax		0	0	0
Federal and state income tax expense	19,740	31,656	54,748	61,935
Net income	57,783	53,833	121,873	119,557
Additions to long-lived assets	65,073	76,213	159,836	152,082
Equity investment in investees	14,532		14,532		14,532
Total segment assets	$ 3,840,131		$ 3,840,131		$ 3,726,471

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies, Stock-Based Compensation (Details) (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended		9 Months Ended		3 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012 Non-vested Stock [Member]	Sep. 30, 2011 Non-vested Stock [Member]	Sep. 30, 2012 Non-vested Stock [Member]	Sep. 30, 2011 Non-vested Stock [Member]	Sep. 30, 2012 Stock Options [Member]	Sep. 30, 2011 Stock Options [Member]	Sep. 30, 2012 Stock Options [Member]	Sep. 30, 2011 Stock Options [Member]	Sep. 30, 2012 Equity Classification [Member]	Sep. 30, 2011 Equity Classification [Member]	Sep. 30, 2012 Equity Classification [Member]	Sep. 30, 2011 Equity Classification [Member]	Sep. 30, 2012 Cleco Power [Member]	Sep. 30, 2011 Cleco Power [Member]	Sep. 30, 2012 Cleco Power [Member]	Sep. 30, 2011 Cleco Power [Member]	Sep. 30, 2012 Cleco Power [Member] Non-vested Stock [Member]	Sep. 30, 2011 Cleco Power [Member] Non-vested Stock [Member]	Sep. 30, 2012 Cleco Power [Member] Non-vested Stock [Member]	Sep. 30, 2011 Cleco Power [Member] Non-vested Stock [Member]	Sep. 30, 2012 Cleco Power [Member] Stock Options [Member]	Sep. 30, 2011 Cleco Power [Member] Stock Options [Member]	Sep. 30, 2012 Cleco Power [Member] Stock Options [Member]	Sep. 30, 2011 Cleco Power [Member] Stock Options [Member]	Sep. 30, 2012 Cleco Power [Member] Equity Classification [Member]	Sep. 30, 2011 Cleco Power [Member] Equity Classification [Member]	Sep. 30, 2012 Cleco Power [Member] Equity Classification [Member]	Sep. 30, 2011 Cleco Power [Member] Equity Classification [Member]	Mar. 31, 2012 Certain Officers, Key Employees, and Directors [Member] Non-vested Stock [Member]
Stock-Based Compensation [Line Items]
Number of shares granted																																	140,186
Share-based compensation expense	$ 1,988	$ 2,188	$ 4,834	$ 5,730	$ 1,139	$ 1,095	$ 3,271	$ 3,042	$ 2	$ 69	$ 11	$ 105	$ 1,141	$ 1,164	$ 3,282	$ 3,147	$ 639	$ 660	$ 1,423	$ 1,768	$ 301	$ 225	$ 792	$ 748	$ 0	$ 0	$ 0	$ 0	$ 301	$ 225	$ 792	$ 748
Common stock equivalent units	847	1,024	1,552	2,583													338	435	631	1,020
Tax benefit (excluding income tax gross-up)	$ 765	$ 842	$ 1,860	$ 2,205													$ 246	$ 254	$ 548	$ 680

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Disclosures about Segments (Policies)

9 Months Ended

Sep. 30, 2012

Segment Reporting [Abstract]

Segment Reporting, Policy [Policy Text Block]

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.

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Income Taxes (Policies)

9 Months Ended

Sep. 30, 2012

Income Tax Disclosure [Abstract]

Income Tax, Policy [Policy Text Block]

Uncertain Tax Positions

Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest 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.

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Pension Plan and Employee Benefits, 401 (K) Plans (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
401(k) Plan [Abstract]
401 (k) Plan expense	$ 963	$ 945	$ 3,303	$ 2,998
Other Subsidiaries [Member]
401(k) Plan [Abstract]
401 (k) Plan expense	$ 200	$ 200	$ 800	$ 700

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Regulatory Assets and Liabilities, Summary of Regulatory Assets and Liabilities (Details) (USD $)	9 Months Ended			9 Months Ended																	9 Months Ended	12 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011	Sep. 30, 2012 Cleco Power [Member]	Sep. 30, 2011 Cleco Power [Member]	Dec. 31, 2011 Cleco Power [Member]	Sep. 30, 2012 Cleco Power [Member] Total regulatory assets - other [Member]	Dec. 31, 2011 Cleco Power [Member] Total regulatory assets - other [Member]	Sep. 30, 2012 Cleco Power [Member] Mining costs [Member]	Dec. 31, 2011 Cleco Power [Member] Mining costs [Member]	Sep. 30, 2012 Cleco Power [Member] Interest costs [Member]	Dec. 31, 2011 Cleco Power [Member] Interest costs [Member]	Sep. 30, 2012 Cleco Power [Member] Asset removal costs [Member]	Dec. 31, 2011 Cleco Power [Member] Asset removal costs [Member]	Sep. 30, 2012 Cleco Power [Member] Postretirement plan costs [Member]	Dec. 31, 2011 Cleco Power [Member] Postretirement plan costs [Member]	Sep. 30, 2012 Cleco Power [Member] Tree trimming costs [Member]	Dec. 31, 2011 Cleco Power [Member] Tree trimming costs [Member]	Sep. 30, 2012 Cleco Power [Member] Training costs [Member]	Dec. 31, 2011 Cleco Power [Member] Training costs [Member]	Sep. 30, 2012 Cleco Power [Member] Storm surcredits, net [Member]	Dec. 31, 2011 Cleco Power [Member] Storm surcredits, net [Member]	Sep. 30, 2012 Cleco Power [Member] Construction carrying costs - asset [Member]	Dec. 31, 2011 Cleco Power [Member] Construction carrying costs - asset [Member]	Sep. 30, 2012 Cleco Power [Member] Lignite mining agreement contingency [Member]	Dec. 31, 2011 Cleco Power [Member] Lignite mining agreement contingency [Member]	Sep. 30, 2012 Cleco Power [Member] Power purchase agreement capacity costs [Member]	Dec. 31, 2011 Cleco Power [Member] Power purchase agreement capacity costs [Member]	Sep. 30, 2012 Cleco Power [Member] AFUDC equity gross-up [Member]	Dec. 31, 2011 Cleco Power [Member] AFUDC equity gross-up [Member]	Sep. 30, 2012 Cleco Power [Member] Rate case costs [Member]	Dec. 31, 2011 Cleco Power [Member] Rate case costs [Member]	Sep. 30, 2012 Cleco Power [Member] Acadia Unit 1 acquisition costs [Member]	Dec. 31, 2011 Cleco Power [Member] Acadia Unit 1 acquisition costs [Member]	Sep. 30, 2012 Cleco Power [Member] IRP/RFP costs [Member]	Dec. 31, 2011 Cleco Power [Member] IRP/RFP costs [Member]	Sep. 30, 2012 Cleco Power [Member] AMI pilot costs [Member]	Dec. 31, 2011 Cleco Power [Member] AMI pilot costs [Member]	Sep. 30, 2012 Cleco Power [Member] Financing costs [Member]	Dec. 31, 2011 Cleco Power [Member] Financing costs [Member]	Sep. 30, 2012 Cleco Power [Member] Biomass costs [Member]	Dec. 31, 2011 Cleco Power [Member] Biomass costs [Member]	Sep. 30, 2012 Cleco Power [Member] Construction carrying costs - liability [Member]	Dec. 31, 2011 Cleco Power [Member] Construction carrying costs - liability [Member]	Sep. 30, 2012 Cleco Power [Member] Fuel and purchased power [Member]	Dec. 31, 2011 Cleco Power [Member] Fuel and purchased power [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Regulatory assets				$ 6,000,000		$ 9,300,000	$ 271,154,000	$ 282,472,000	$ 17,206,000	$ 19,117,000	$ 6,394,000	$ 6,667,000	$ 851,000	$ 829,000	$ 126,349,000	$ 132,556,000	$ 6,335,000	$ 8,371,000	$ 7,369,000	$ 7,486,000	$ 5,958,000	$ 9,254,000	$ 6,262,000	$ 10,883,000	$ 3,781,000	$ 3,781,000	$ 5,921,000	$ 0	$ 73,906,000	$ 74,346,000	$ 716,000	$ 1,117,000	$ 2,892,000	$ 2,971,000	$ 156,000	$ 508,000	$ 54,000	$ 153,000	$ 6,851,000	$ 4,433,000	$ 153,000	$ 0			$ 1,715,000	$ 2,136,000
Regulatory liabilities																																											(8,251,000)	(40,322,000)
Total regulatory assets, net				484,051,000		458,707,000
Regulatory assets and liabilities - deferred taxes, net	219,433,000		214,421,000	219,433,000		214,421,000
Increase (Decrease) in Regulatory Assets and Liabilities	$ 30,532,000	$ 40,204,000		$ 30,532,000	$ 40,204,000																$ 3,300,000	$ 1,600,000

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Variable Interest Entities (Policies)

9 Months Ended

Sep. 30, 2012

Variable Interest Entities [Abstract]

Consolidation, Variable Interest Entity, 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.

Prior to April 30, 2011, Cleco Corporation also reported its investment in Cajun on the equity method of accounting. In conjunction with the disposition of Acadia Unit 2, APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH.

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.

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Summary of Significant Accounting Policies (Tables)

9 Months Ended

Sep. 30, 2012

Accounting Policies [Abstract]

Property, Plant and Equipment

Property, plant, and equipment consisted of:

(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Regulated utility plants	$	3,815,608		$	3,759,541
Other	267,028			264,114
Total property, plant, and equipment	4,082,636			4,023,655
Accumulated depreciation	(1,291,862		)	(1,230,783		)
Net property, plant, and equipment	$	2,790,774		$	2,792,872

Restricted Cash

Cleco’s restricted cash and cash equivalents consisted of:  

(THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
Diversified Lands’ mitigation escrow	$	97	$	97
Cleco Katrina/Rita’s storm recovery bonds	3,406		8,761
Cleco Power’s future storm restoration costs	11,510		24,876
Cleco Power’s renewable energy grant	—		381
Cleco Power’s NOx allowance escrow	1,713		1,713
Total restricted cash and cash equivalents	$	16,726	$	35,828

Reclassifications

The corrections to the September 30, 2011 Condensed Consolidated Statements of Cash Flows are presented in the following table:

				CLECO						CLECO POWER
	FOR THE NINE MONTHS ENDED SEPT. 30, 2011
(THOUSANDS)	AS REPORTED			AS ADJUSTED			AS REPORTED			AS ADJUSTED
Accounts receivable	$	(18,274	)	$	(21,691	)	$	(20,442	)	$	(23,859	)
Other deferred accounts	$	(2,184	)	$	2,181		$	(6,361	)	$	(1,996	)
Net cash provided by operating activities	$	262,642		$	263,590		$	184,688		$	185,636
Additions to property, plant, and equipment	$	(145,669	)	$	(146,617	)	$	(131,014	)	$	(131,962	)
Net cash used in investing activities	$	(54,097	)	$	(55,045	)	$	(112,856	)	$	(113,804	)
Net decrease in cash and cash equivalents	$	(32,896	)	$	(32,896	)	$	(41,897	)	$	(41,897	)
Cash and cash equivalents at the beginning of the period	$	191,128		$	191,128		$	184,912		$	184,912
Cash and cash equivalents at the end of the period	$	158,232		$	158,232		$	143,015		$	143,015

Earnings per Average Common Share

The following tables show the calculation of basic and diluted earnings per share:

						FOR THE THREE MONTHS ENDED SEPT. 30,
				2012					2011
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Basic net income applicable to common stock	$	63,818	60,346,476	$	1.06	$	65,842	60,467,595	$	1.09
Effect of dilutive securities
Add:  stock option grants			1,536					20,441
Add:  restricted stock (LTICP)			251,191					385,275
Diluted net income applicable to common stock	$	63,818	60,599,203	$	1.05	$	65,842	60,873,311	$	1.08

						FOR THE NINE MONTHS ENDED SEPT. 30,
				2012					2011
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Net income	$	140,536				$	165,205
Deduct:  non-participating stock dividends (4.5% preferred stock)	—					26
Deduct:  non-participating stock redemption costs (4.5% preferred stock)	—					112
Basic net income applicable to common stock	$	140,536	60,375,538	$	2.33	$	165,067	60,549,860	$	2.73
Effect of dilutive securities
Add:  stock option grants			4,518					20,965
Add:  restricted stock (LTICP)			246,415					259,426
Diluted net income applicable to common stock	$	140,536	60,626,471	$	2.32	$	165,067	60,830,251	$	2.71

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				CLECO CORPORATION				CLECO POWER
	FOR THE THREE MONTHS ENDED SEPT. 30,								FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011		2012		2011		2012		2011
Equity classification
Non-vested stock	$	1,139	$	1,095	$	301	$	225	$	3,271	$	3,042	$	792	$	748
Stock options	2		69		—		—		11		105		—		—
Total equity classification	$	1,141	$	1,164	$	301	$	225	$	3,282	$	3,147	$	792	$	748
Liability classification
Common stock equivalent units	$	847	$	1,024	$	338	$	435	$	1,552	$	2,583	$	631	$	1,020
Total pre-tax compensation expense	$	1,988	$	2,188	$	639	$	660	$	4,834	$	5,730	$	1,423	$	1,768
Tax benefit	$	765	$	842	$	246	$	254	$	1,860	$	2,205	$	548	$	680

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Summary of Significant Accounting Policies

9 Months Ended

Sep. 30, 2012

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 pursuant to the rules and regulations of the SEC. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted; however, Cleco believes that the disclosures are adequate to make the information presented not misleading.

The year-end condensed consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by GAAP. The unaudited financial information included in the condensed consolidated financial statements of Cleco Corporation and Cleco Power reflects all adjustments of a normal recurring nature which are, in the opinion of the management of Cleco Corporation and Cleco Power, necessary for a fair statement of the financial position and the results of operations for the interim periods. Information for interim periods is affected by seasonal variations in sales, rate changes, timing of fuel expense recovery, and other factors, and is not indicative necessarily of the results that may be expected for the full fiscal year. 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 consist 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. Property, plant, and equipment consisted of:

(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Regulated utility plants	$	3,815,608		$	3,759,541
Other	267,028			264,114
Total property, plant, and equipment	4,082,636			4,023,655
Accumulated depreciation	(1,291,862		)	(1,230,783		)
Net property, plant, and equipment	$	2,790,774		$	2,792,872

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 SEPT. 30, 2012		AT DEC. 31, 2011
Diversified Lands’ mitigation escrow	$	97	$	97
Cleco Katrina/Rita’s storm recovery bonds	3,406		8,761
Cleco Power’s future storm restoration costs	11,510		24,876
Cleco Power’s renewable energy grant	—		381
Cleco Power’s NOx allowance escrow	1,713		1,713
Total restricted cash and cash equivalents	$	16,726	$	35,828

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 operating expenses, interest, and principal on storm recovery bonds. During the nine months ended September 30, 2012, Cleco Katrina/Rita collected $14.7 million net of operating expenses. In March and September 2012, Cleco Katrina/Rita used $6.7 million and $6.4 million, respectively for scheduled storm recovery bond principal payments and $3.6 million and $3.4 million, respectively for related interest. Cleco Power's restricted cash and cash equivalents held for future storm restoration costs decreased $13.4 million from December 31, 2011, primarily due to the transfer of $4.5 million to restricted investments and the transfer of $10.0 million to cover expenses associated with Hurricane Isaac. These amounts were partially offset by $1.1 million of storm surcredits. For more information about these restricted investments, see Note 4 — "Fair Value Accounting — Restricted Investments" and for more information about Hurricane Isaac, see Note 14 — "Storm Restoration."

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. Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the condensed consolidated balance sheets with their fair values as of the balance sheet date disclosed within the three levels. For more information about fair value levels, see Note 4 — “Fair Value Accounting.”

Risk Management

Market risk inherent in Cleco Power’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power and natural gas 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 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 enter into positions 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. When these positions close, actual gains or losses will be included in the fuel adjustment clause and reflected on customers’ bills as a component of the fuel cost adjustment.

Cleco Power maintains margin accounts with commodity brokers used to partially fund the acquisition of natural gas futures, options, and swap contracts. These contracts/positions are used to mitigate the risks associated with the volatility in customer fuel costs noted above. The current and long-term portions of collateral are reported as a component of energy risk management assets or liabilities and other deferred credits, respectively.

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 these contracts in which Cleco is hedging the variability of cash flows related to forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy, and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified as earnings in the periods in which earnings are affected by the variability of the cash flows of the hedged item. The ineffective portions of hedges will be recognized in current period earnings unless management determines that it is probable that the costs will be recovered through the rate-making process. If management determines that it is probable that the costs will be recovered, then they will be recognized as a regulatory asset or liability and amortized to earnings over the life of the related debt. For those contracts in which Cleco is hedging the variability of cash flows related to forecasted transactions that do not qualify as cash flow hedges, the changes in the fair value of such derivative instruments will be recognized in current period earnings unless management determines that it is probable that the costs will be recovered through the rate-making process. If management determines that it is probable that the costs will be recovered, then such costs will be recognized as a regulatory asset or liability and amortized to earnings over the life of the related debt. For more information on the interest rate risk contracts, see Note 4 — “Fair Value Accounting — Interest Rate Derivatives.”

Reclassifications

Certain reclassifications have been made to the 2011 financial statements to conform them to the presentation used in the 2012 financial statements. These reclassifications had no effect on Cleco Corporation’s net income applicable to common stock or total common shareholders’ equity or Cleco Power’s net income or total member’s equity.

During the second quarter of 2012, the Registrants began presenting the LPSC allowable portion of the amortization of the plant acquisition adjustment related to Acadia Unit 1 as depreciation expense on the Registrants’ Condensed Consolidated Statements of Income. Previously, this amortization was presented as other expense. The Registrants have reclassified prior year amounts to conform to this presentation. This change increased depreciation and decreased other expenses by $0.7 million and $2.1 million for the three and nine months ended September 30, 2011, respectively.

Also during the second quarter of 2012, the Registrants determined that an error existed in the statement of cash flows presentation of contributions received in aid of construction, specifically the impact that the accounting for these contributions had on the presentation of cash flows related to the additions of property, plant, and equipment. This caused errors between the operating activities section and investing activities section for prior periods.

Cleco and Cleco Power’s Condensed Consolidated Statements of Cash Flows for the nine months ended September 30, 2011, have been adjusted to correct the presentation of cash flows related to additions to property, plant, and equipment. These corrections had no impact on the Registrants’ cash and cash equivalents, financial condition, or results of operations. Management believes that these corrections did not have a material effect on the Registrants’ Condensed Consolidated Statements of Cash Flows. The corrections to the September 30, 2011 Condensed Consolidated Statements of Cash Flows are presented in the following table:

				CLECO						CLECO POWER
	FOR THE NINE MONTHS ENDED SEPT. 30, 2011
(THOUSANDS)	AS REPORTED			AS ADJUSTED			AS REPORTED			AS ADJUSTED
Accounts receivable	$	(18,274	)	$	(21,691	)	$	(20,442	)	$	(23,859	)
Other deferred accounts	$	(2,184	)	$	2,181		$	(6,361	)	$	(1,996	)
Net cash provided by operating activities	$	262,642		$	263,590		$	184,688		$	185,636
Additions to property, plant, and equipment	$	(145,669	)	$	(146,617	)	$	(131,014	)	$	(131,962	)
Net cash used in investing activities	$	(54,097	)	$	(55,045	)	$	(112,856	)	$	(113,804	)
Net decrease in cash and cash equivalents	$	(32,896	)	$	(32,896	)	$	(41,897	)	$	(41,897	)
Cash and cash equivalents at the beginning of the period	$	191,128		$	191,128		$	184,912		$	184,912
Cash and cash equivalents at the end of the period	$	158,232		$	158,232		$	143,015		$	143,015

Earnings per Average Common Share

The following tables show the calculation of basic and diluted earnings per share:

						FOR THE THREE MONTHS ENDED SEPT. 30,
				2012					2011
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Basic net income applicable to common stock	$	63,818	60,346,476	$	1.06	$	65,842	60,467,595	$	1.09
Effect of dilutive securities
Add:  stock option grants			1,536					20,441
Add:  restricted stock (LTICP)			251,191					385,275
Diluted net income applicable to common stock	$	63,818	60,599,203	$	1.05	$	65,842	60,873,311	$	1.08

						FOR THE NINE MONTHS ENDED SEPT. 30,
				2012					2011
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Net income	$	140,536				$	165,205
Deduct:  non-participating stock dividends (4.5% preferred stock)	—					26
Deduct:  non-participating stock redemption costs (4.5% preferred stock)	—					112
Basic net income applicable to common stock	$	140,536	60,375,538	$	2.33	$	165,067	60,549,860	$	2.73
Effect of dilutive securities
Add:  stock option grants			4,518					20,965
Add:  restricted stock (LTICP)			246,415					259,426
Diluted net income applicable to common stock	$	140,536	60,626,471	$	2.32	$	165,067	60,830,251	$	2.71

Stock option grants are excluded from the computation of diluted earnings per share if the exercise price is higher than the average market price. There were no stock option grants excluded from the computation of diluted earnings per share for the three and nine months ended September 30, 2012 and 2011, due to the average market price being higher than the exercise prices of the stock options.

Stock-Based Compensation

At September 30, 2012, 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 first quarter of 2012, Cleco granted 140,186 shares of non-vested stock to certain officers, key employees, and directors 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				CLECO CORPORATION				CLECO POWER
	FOR THE THREE MONTHS ENDED SEPT. 30,								FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011		2012		2011		2012		2011
Equity classification
Non-vested stock	$	1,139	$	1,095	$	301	$	225	$	3,271	$	3,042	$	792	$	748
Stock options	2		69		—		—		11		105		—		—
Total equity classification	$	1,141	$	1,164	$	301	$	225	$	3,282	$	3,147	$	792	$	748
Liability classification
Common stock equivalent units	$	847	$	1,024	$	338	$	435	$	1,552	$	2,583	$	631	$	1,020
Total pre-tax compensation expense	$	1,988	$	2,188	$	639	$	660	$	4,834	$	5,730	$	1,423	$	1,768
Tax benefit	$	765	$	842	$	246	$	254	$	1,860	$	2,205	$	548	$	680

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Regulatory Assets and Liabilities (Tables)

9 Months Ended

Sep. 30, 2012

Regulatory Assets and Liabilities Disclosure [Abstract]

Regulatory Assets and Liabilities

The following table summarizes Cleco Power’s regulatory assets and liabilities at September 30, 2012 and December 31, 2011:

(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Regulatory assets – deferred taxes, net	$	219,433		$	214,421
Mining costs	$	17,206		$	19,117
Interest costs	6,394			6,667
Asset removal costs	851			829
Postretirement plan costs	126,349			132,556
Tree trimming costs	6,335			8,371
Training costs	7,369			7,486
Storm surcredits, net	5,958			9,254
Construction carrying costs	6,262			10,883
Lignite mining agreement contingency	3,781			3,781
Power purchase agreement capacity costs	5,921			—
AFUDC equity gross-up	73,906			74,346
Rate case costs	716			1,117
Acadia Unit 1 acquisition costs	2,892			2,971
IRP/RFP costs	156			508
AMI pilot costs	54			153
Financing costs	6,851			4,433
Biomass costs	153			—
Total regulatory assets – other	$	271,154		$	282,472
Construction carrying costs	(8,251		)	(40,322		)
Fuel and purchased power	1,715			2,136
Total regulatory assets, net	$	484,051		$	458,707

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Summary of Significant Accounting Policies, Restricted Cash and Cash Equivalents (Details) (USD $)	1 Months Ended		9 Months Ended
	Sep. 30, 2012	Mar. 31, 2012	Sep. 30, 2012	Dec. 31, 2011
Restricted Cash and Cash Equivalents Abstract]
Restricted cash and cash equivalents	$ 16,726,000		$ 16,726,000	$ 35,828,000
Diversified Lands Mitigation Escrow Agreement [Member]
Restricted Cash and Cash Equivalents Abstract]
Restricted cash and cash equivalents	97,000		97,000	97,000
Katrina/Rita Bond Payments [Member]
Restricted Cash and Cash Equivalents Abstract]
Restricted cash and cash equivalents	3,406,000		3,406,000	8,761,000
Collection net of operating expenses			14,700,000
Bond principal payments	6,400,000	6,700,000
Bond interest payments	3,400,000	3,600,000
Future Storm Restoration Costs [Member]
Restricted Cash and Cash Equivalents Abstract]
Restricted cash and cash equivalents	11,510,000		11,510,000	24,876,000
Increase (decrease) in restricted cash and cash equivalents			(13,400,000)
Future Storm Restoration Costs [Member] | Transfer to Restricted Investments [Member]
Restricted Cash and Cash Equivalents Abstract]
Restricted Cash and Cash Equivalents, Transfers			(4,500,000)
Future Storm Restoration Costs [Member] | Transfer to cover storm related expenses [Member]
Restricted Cash and Cash Equivalents Abstract]
Restricted Cash and Cash Equivalents, Transfers			(10,000,000)
Future Storm Restoration Costs [Member] | Increase in Storm Surcredits [Member]
Restricted Cash and Cash Equivalents Abstract]
Increase (decrease) in restricted cash and cash equivalents			1,100,000
Renewable Energy Grant [Member]
Restricted Cash and Cash Equivalents Abstract]
Restricted cash and cash equivalents	0		0	381,000
Nox Allowance Escrow [Member]
Restricted Cash and Cash Equivalents Abstract]
Restricted cash and cash equivalents	$ 1,713,000		$ 1,713,000	$ 1,713,000

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Debt (Details) (USD $)	9 Months Ended
	Sep. 30, 2012	Dec. 31, 2011
Debt Instrument [Line Items]
Short-term debt	$ 0	$ 0
Long-term outstanding	1,330,000,000
Long-term due within one year	90,900,000
Repayments of long-term debt	(33,200,000)
Capital lease payments	500,000
Debt premium amortizations	700,000
Line of Credit Facility, Amount Outstanding	0
Cleco Power [Member]
Debt Instrument [Line Items]
Short-term debt	0	0
Line of Credit Facility, Amount Outstanding		0
Cleco Powers Senior Notes 4.33% due 2027 [Member]
Debt Instrument [Line Items]
Principal amount of debt	50,000,000
Interest rate (in hundredths)	4.33%
Debt Instrument, Maturity Date	May 15, 2027
Cleco Powers Senior Notes 4.33% due 2027 [Member] | Cleco Power [Member]
Debt Instrument [Line Items]
Debt Instrument, Maturity Date	May 15, 2027
Cleco Katrina/Ritas Storm Recovery Bonds [Member]
Debt Instrument [Line Items]
Long-term due within one year	14,000,000
Capital lease payments	1,900,000
Cleco Power Senior Notes 5.375% Due 2013 [Member]
Debt Instrument [Line Items]
Long-term due within one year	75,000,000
Cleco Corporation's credit facility draws [Member]
Debt Instrument [Line Items]
Decrease in credit facility	(10,000,000)
Bonds [Member] | Cleco Power's DeSoto Parish pollution control revenue bonds [Member]
Debt Instrument [Line Items]
Interest accrued	600,000
Interest rate (in hundredths)	5.875%
Repayments of long-term debt	(50,100,000)
Debt Instrument, Maturity Date	Sep. 01, 2029
Bonds [Member] | Cleco Power's Rapides Parish pollution control revenue bonds[Member]
Debt Instrument [Line Items]
Interest accrued	300,000
Interest rate (in hundredths)	5.875%
Repayments of long-term debt	(11,200,000)
Debt Instrument, Maturity Date	Sep. 01, 2029
Bonds [Member] | Cleco Katrina/Ritas Storm Recovery Bonds [Member]
Debt Instrument [Line Items]
Scheduled payment	$ (13,100,000)

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Storm Restoration Storm Restoration (Details) (Cleco Power [Member], Hurricane Isaac [Member], USD $) In Millions, unless otherwise specified	Sep. 30, 2012	Sep. 02, 2012	Aug. 28, 2012 customer
Cleco Power [Member] | Hurricane Isaac [Member]
Storm Resotration [Line Items]
Approximate Number of Customers Affected			95,000
Percent of Customers Affected			34.00%
Percent of Customers Restored		100.00%
Cost of Storm Restoration	$ 21.4
Percent of Storm Restoration Costs Capitalized	61.80%
Capitalized Storm Restoration Costs	$ 13.2

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Consolidated Statements of Income (USD $) In Thousands, except Share data, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Operating revenue
Electric operations	$ 282,894	$ 324,532	$ 720,776	$ 823,484
Tolling operations	0	9,133	0	16,137
Other operations	15,408	16,064	38,464	41,775
Affiliate revenue	0	0	0	202
Gross operating revenue	298,302	349,729	759,240	881,598
Electric customer credits	(930)	1,852	1,025	(3,405)
Operating revenue, net	297,372	351,581	760,265	878,193
Operating expenses
Fuel used for electric generation	79,701	122,774	207,764	298,009
Power purchased for utility customers	19,364	25,473	44,069	60,590
Other operations	30,517	32,138	86,901	90,281
Maintenance	20,059	14,587	61,478	59,666
Depreciation	34,931	31,237	99,028	91,749
Taxes other than income taxes	9,455	9,845	29,198	28,770
(Gain) loss on sales of assets	(2)	27	(57)	(468)
Total operating expenses	194,025	236,081	528,381	628,597
Operating income	103,347	115,500	231,884	249,596
Interest income	132	509	163	794
Allowance for other funds used during construction	1,882	902	4,298	3,757
Equity income (loss) from investees, before tax	0	(1)	1	62,051
Other income	1,834	2,128	24,223	3,330
Other expense	(1,232)	(2,680)	(2,718)	(2,861)
Interest charges
Interest charges, including amortization of debt expenses, premium and discount, net	22,610	26,105	64,671	79,368
Allowance for borrowed funds used during construction	(644)	(326)	(1,466)	(1,357)
Total interest charges	21,966	25,779	63,205	78,011
Income before income taxes	83,997	90,579	194,646	238,656
Federal and state income tax expense	20,179	24,737	54,110	73,451
Net income	63,818	65,842	140,536	165,205
Preferred dividends requirements			0	26
Preferred stock redemption costs			0	112
Net income applicable to common stock	63,818	65,842	140,536	165,067
Average shares of common stock outstanding
Average number of basic common shares outstanding (in shares)	60,346,476	60,467,595	60,375,538	60,549,860
Average number of diluted common shares outstanding (in shares)	60,599,203	60,873,311	60,626,471	60,830,251
Basic earnings per share
Net income applicable to common stock (in dollars per share)	$ 1.06	$ 1.09	$ 2.33	$ 2.73
Diluted earnings per share
Net income applicable to common stock (in dollars per share)	$ 1.05	$ 1.08	$ 2.32	$ 2.71
Cash dividends paid per share of common stock (in dollars per share)	$ 0.3375	$ 0.28	$ 0.9625	$ 0.81
Cleco Power [Member]
Operating revenue
Electric operations	282,894	324,532	720,776	823,484
Tolling operations	0	0	0	0
Other operations	14,905	15,565	36,967	40,261
Affiliate revenue	343	347	1,030	1,041
Gross operating revenue	298,142	340,444	758,773	864,786
Electric customer credits	(930)	1,852	1,025	(3,405)
Operating revenue, net	297,212	342,296	759,798	861,381
Operating expenses
Fuel used for electric generation	79,701	122,774	207,459	298,009
Power purchased for utility customers	33,254	25,473	65,493	60,590
Other operations	29,063	30,451	82,647	85,162
Maintenance	16,095	15,768	51,739	53,962
Depreciation	33,199	29,539	93,847	86,650
Taxes other than income taxes	8,390	8,802	26,004	25,585
(Gain) loss on sales of assets	0	(6)	(1)	(7)
Total operating expenses	199,702	232,801	527,188	609,951
Operating income	97,510	109,495	232,610	251,430
Interest income	129	276	153	557
Allowance for other funds used during construction	1,882	902	4,298	3,757
Equity income (loss) from investees, before tax		0	0	0
Other income	1,188	1,323	3,511	2,168
Other expense	(1,224)	(1,201)	(2,698)	(2,391)
Interest charges
Interest charges, including amortization of debt expenses, premium and discount, net	22,606	25,632	62,719	75,386
Allowance for borrowed funds used during construction	(644)	(326)	(1,466)	(1,357)
Total interest charges	21,962	25,306	61,253	74,029
Income before income taxes	77,523	85,489	176,621	181,492
Federal and state income tax expense	19,740	31,656	54,748	61,935
Net income	$ 57,783	$ 53,833	$ 121,873	$ 119,557

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Regulatory Assets and Liabilities, Additional Disclosures (Details) (USD $)					1 Months Ended	9 Months Ended
	Sep. 30, 2012	Dec. 31, 2011	Sep. 30, 2012 Cleco Power [Member]	Dec. 31, 2011 Cleco Power [Member]	Feb. 28, 2006 Cleco Power [Member] Construction carrying costs - liability [Member]	Sep. 30, 2012 Cleco Power [Member] Construction carrying costs - liability [Member]	Sep. 30, 2012 Cleco Power [Member] Biomass costs [Member]	Sep. 30, 2012 Treasury Rate Locks [Member] Cleco Power [Member] Financing costs [Member]	Dec. 31, 2011 Treasury Rate Locks [Member] Cleco Power [Member] Financing costs [Member]
Schedule of Regulatory Assets and Liabilities, Net [Line Items]
Original recovery period (in years)							5 years	30 years
Revised recovery period (in years)						4 years
Deferred Construction Carrying Costs [Abstract]
Percentage of jurisdictional portion of construction carrying costs to be collected from customers (in hundredths)					75.00%
Amount of construction carrying costs returned to customers						$ 158,200,000
Settlement amount									26,800,000
Number of treasury rate locks entered into									2
Hedge ineffectivness									6,900,000
Regulatory Liabilities	$ 8,251,000	$ 33,019,000	$ 8,251,000	$ 33,019,000		$ 8,300,000

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Consolidated Balance Sheets (Parenthetical) (USD $) In Thousands, except Share data, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Current assets
Customer accounts receivable, allowance for doubtful accounts	$ 1,031	$ 1,128
Other accounts receivable, allowance for doubtful accounts	26	8
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)	60,956,882	60,702,342
Common stock, outstanding (in shares)	60,350,481	60,291,939
Treasury stock, at cost (in shares)	606,401	410,403
Cleco Power [Member]
Current assets
Customer accounts receivable, allowance for doubtful accounts	1,031	1,128
Other accounts receivable, allowance for doubtful accounts	$ 26	$ 8

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Income Taxes, Net Operating Losses (Details) (Federal [Member], USD $) In Millions, unless otherwise specified	Dec. 31, 2011
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards	$ 477.7
Cleco Power [Member]
Operating Loss Carryforwards [Line Items]
Net operating loss carryforwards	$ 436.9

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Income Taxes (Tables)

9 Months Ended

Sep. 30, 2012

Effective Income Tax Rates

The following table summarizes the effective income tax rates for Cleco and Cleco Power for the three and nine month periods ended September 30, 2012 and 2011.

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
	2012		2011		2012		2011
Cleco	24.0	%	27.3	%	27.8	%	30.8	%
Cleco Power	25.5	%	37.0	%	31.0	%	34.1	%

Liability and Expense Related to Unrecognized Tax Benefits

The total amounts of uncertain tax positions and related interest payable and interest expense, as reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets and Statements of Income, are shown in the following tables.

(THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
Interest payable
Cleco	$	2,166	$	13,843
Cleco Power	$	5,502	$	17,327

	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012			2011
Interest charges
Cleco	$	(121	)	$	93		$	(8,477	)	$	2,954
Cleco Power	$	133		$	(420	)	$	(9,504	)	$	1,356

The total liability for unrecognized tax benefits for Cleco at September 30, 2012 and December 31, 2011, is shown in the following table.

Cleco
(THOUSANDS)	LIABILITY FOR UNRECOGNIZED TAX BENEFITS
Balance at December 31, 2011	$	56,235
Additions for tax positions of current period	640
Reductions for tax positions of current period	—
Additions for tax positions of prior periods	—
Reduction for tax positions of prior periods	22,418
Reduction for settlement with tax authority	32,062
Reduction for lapse of statute of limitations	—
Balance at September 30, 2012	$	2,395

Cleco Power [Member]

Liability and Expense Related to Unrecognized Tax Benefits

The total liability (asset) for unrecognized tax benefits for Cleco Power at September 30, 2012 and December 31, 2011, is shown in the following table.

Cleco Power
(THOUSANDS)	LIABILITY (ASSET) FOR UNRECOGNIZED TAX BENEFITS
Balance at December 31, 2011	$	52,558
Additions for tax positions of current period	640
Reductions for tax positions of current period	—
Additions for tax positions of prior periods	—
Reduction for tax positions of prior periods	21,327
Reduction for settlement with tax authority	32,062
Reduction for lapse of statute of limitations	—
Balance at September 30, 2012	$	(191	)

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Variable Interest Entities (Details) (USD $)	3 Months Ended		9 Months Ended			3 Months Ended		4 Months Ended	9 Months Ended			3 Months Ended		9 Months Ended			3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011	Sep. 30, 2012 Cajun [Member]	Sep. 30, 2011 Cajun [Member]	Apr. 30, 2011 Cajun [Member]	Sep. 30, 2012 Cajun [Member]	Sep. 30, 2011 Cajun [Member]	Apr. 29, 2011 Cajun [Member]	Sep. 30, 2012 Oxbow [Member]	Sep. 30, 2011 Oxbow [Member]	Sep. 30, 2012 Oxbow [Member]	Sep. 30, 2011 Oxbow [Member]	Dec. 31, 2011 Oxbow [Member]	Sep. 30, 2012 Subsidiares Less Than One Hundred Percent Owned By Cleco Innovations LLC Not Primary Beneficiary [Member]	Sep. 30, 2011 Subsidiares Less Than One Hundred Percent Owned By Cleco Innovations LLC Not Primary Beneficiary [Member]	Sep. 30, 2012 Subsidiares Less Than One Hundred Percent Owned By Cleco Innovations LLC Not Primary Beneficiary [Member]	Sep. 30, 2011 Subsidiares Less Than One Hundred Percent Owned By Cleco Innovations LLC Not Primary Beneficiary [Member]	Sep. 30, 2012 Maximum [Member] Subsidiares Less Than One Hundred Percent Owned By Cleco Innovations LLC Not Primary Beneficiary [Member]
Variable Interest Entity [Line Items]
Value of plant acquisition (proceeds)											$ (298,800,000)
Variable interest entity, ownership percentage (in hundredths)														50.00%
Ownership percentage by other parties (in hundredths)														50.00%
Summarized financial information [Abstract]
Current assets												1,753,000		1,753,000		1,711,000
Property, plant and equipment, net												23,119,000		23,119,000		23,339,000
Other assets												4,247,000		4,247,000		4,128,000
Total assets												29,119,000		29,119,000		29,178,000
Current liabilities												24,000		24,000		40,000
Other liabilities												30,000		30,000		73,000
Partner's capital												29,065,000		29,065,000		29,065,000
Total liabilities and partners' capital												29,119,000		29,119,000		29,178,000
Operating revenue										5,227,000		450,000	382,000	1,125,000	880,000
Operating expenses										5,914,000		450,000	382,000	1,125,000	880,000
EquityMethodInvestmentSummarizedFinancialInformationGainOnSalesOfAssets										71,422,000
Other income										929,000
Income (loss) before taxes										71,664,000		0	0	0	0
Equity method investment, income tax expense (benefit)								24,000,000
Equity income (loss) from equity method investments [Abstract]
Total equity income (loss)	0	(1,000)	1,000	62,051,000		0	0		0	62,053,000							0	(1,000)	1,000	(2,000)
Components of equity method investments [Abstract]
Purchase price												12,873,000		12,873,000		12,873,000
Cash contributions												1,659,000		1,659,000		1,659,000
Total equity investment in investee	14,541,000		14,541,000		14,540,000							14,532,000		14,532,000		14,532,000					100,000
Comparison of carrying amount of assets and liabilities to maximum loss exposure [Abstract]
Net assets/liabilities												29,065,000		29,065,000		29,065,000
Entity's 50% equity												14,532,000		14,532,000		14,532,000
Cleco's maximum exposure to loss												$ 14,532,000		$ 14,532,000		$ 14,532,000

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Subsequent Events

9 Months Ended

Sep. 30, 2012

Subsequent Events [Abstract]

Subsequent Event

Note 15 — Subsequent Event

On October 30, 2012, Cleco Power announced Evangeline as the winning bidder in Cleco Power's 2012 Long-Term RFP, subject to further due diligence, the completion of definitive agreements, and regulatory approvals from the LPSC and FERC. The transaction is a transfer of ownership and control of Coughlin Power Station from Evangeline to Cleco Power.  The transaction is expected to be closed in the third quarter of 2013, after the completion of regulatory reviews.

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Disclosures about Segments (Tables)

9 Months Ended

Sep. 30, 2012

Segment Reporting [Abstract]

Segment Information

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED SEPTEMBER 30,
2012 (THOUSANDS)	CLECO POWER			MIDSTREAM			RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	282,894		$	—		$	—		$	—		$	282,894
Tolling operations	—			13,890			—			(13,890		)	—
Other operations	14,905			1			502			—			15,408
Electric customer credits	(930		)	—			—			—			(930		)
Affiliate revenue	343			—			12,343			(12,686		)	—
Operating revenue, net	$	297,212		$	13,891		$	12,845		$	(26,576	)	$	297,372
Depreciation	$	33,199		$	1,499		$	233		$	—		$	34,931
Interest charges	$	21,962		$	(69	)	$	(124	)	$	197		$	21,966
Interest income	$	129		$	—		$	(194	)	$	197		$	132
Federal and state income tax expense (benefit)	$	19,740		$	2,489		$	(2,050	)	$	—		$	20,179
Segment profit	$	57,783		$	3,429		$	2,606		$	—		$	63,818
Additions to long-lived assets	$	65,073		$	799		$	503		$	—		$	66,375
Equity investment in investees	$	14,532		$	—		$	9		$	—		$	14,541
Total segment assets	$	3,840,131		$	221,503		$	194,996		$	(149,737	)	$	4,106,893

2011 (THOUSANDS)	CLECO POWER		MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	324,532	$	—	$	—		$	—		$	324,532
Tolling operations	—		9,133		—			—			9,133
Other operations	15,565		1		500			(2		)	16,064
Electric customer credits	1,852		—		—			—			1,852
Affiliate revenue	347		—		13,448			(13,795		)	$	—
Operating revenue, net	$	342,296	$	9,134	$	13,948		$	(13,797	)	$	351,581
Depreciation	$	29,539	$	1,457	$	241		$	—		$	31,237
Interest charges	$	25,306	$	752	$	(308	)	$	29		$	25,779
Interest income	$	276	$	5	$	199		$	29		$	509
Equity loss from investees, before tax	$	—	$	—	$	(1	)	$	—		$	(1	)
Federal and state income tax expense (benefit)	$	31,656	$	444	$	(7,363	)	$	—		$	24,737
Segment profit	$	53,833	$	5,946	$	6,063		$	—		$	65,842
Additions to long-lived assets	$	76,213	$	4,074	$	81		$	—		$	80,368
Equity investment in investees (1)	$	14,532	$	—	$	8		$	—		$	14,540
Total segment assets  (1)	$	3,726,471	$	233,891	$	201,074		$	(111,234	)	$	4,050,202
(1) Balances as of December 31, 2011

SEGMENT INFORMATION FOR THE NINE MONTHS ENDED SEPTEMBER 30,
2012 (THOUSANDS)	CLECO POWER		MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	720,776	$	—	$	—		$	—		$	720,776
Tolling operations	—		21,434		—			(21,434		)	—
Other operations	36,967		2		1,496			(1		)	38,464
Electric customer credits	1,025		—		—			—			1,025
Affiliate revenue	1,030		—		37,540			(38,570		)	—
Operating revenue	$	759,798	$	21,436	$	39,036		$	(60,005	)	$	760,265
Depreciation	$	93,847	$	4,491	$	689		$	1		$	99,028
Interest charges	$	61,253	$	244	$	1,320		$	388		$	63,205
Interest income	$	153	$	—	$	(379	)	$	389		$	163
Equity income from investees, before tax	$	—	$	—	$	1		$	—		$	1
Federal and state income tax expense (benefit)	$	54,748	$	7,278	$	(7,916	)	$	—		$	54,110
Segment profit	$	121,873	$	11,053	$	7,610		$	—		$	140,536
Additions to long-lived assets	$	159,836	$	6,811	$	1,371		$	—		$	168,018
Equity investment in investees	$	14,532	$	—	$	9		$	—		$	14,541
Total segment assets	$	3,840,131	$	221,503	$	194,996		$	(149,737	)	$	4,106,893

2011 (THOUSANDS)	CLECO POWER			MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	823,484		$	—	$	—		$	—		$	823,484
Tolling operations	—			16,137		—			—			16,137
Other operations	40,261			8		1,511			(5		)	41,775
Electric customer credits	(3,405		)	—		—			—			(3,405		)
Affiliate revenue	1,041			45		37,544			(38,428		)	202
Operating revenue	$	861,381		$	16,190	$	39,055		$	(38,433	)	$	878,193
Depreciation	$	86,650		$	4,370	$	728		$	1		$	91,749
Interest charges	$	74,029		$	1,963	$	1,891		$	128		$	78,011
Interest income	$	557		$	6	$	103		$	128		$	794
Equity income (loss) from investees, before tax	$	—		$	62,053	$	(2	)	$	—		$	62,051
Federal and state income tax expense (benefit)	$	61,935		$	21,296	$	(9,781	)	$	1		$	73,451
Segment profit (1)	$	119,557		$	39,274	$	6,374		$	—		$	165,205
Additions to long-lived assets	$	152,082		$	5,202	$	749		$	—		$	158,033
Equity investment in investees (2)	$	14,532		$	—	$	8		$	—		$	14,540
Total segment assets (2)	$	3,726,471		$	233,891	$	201,074		$	(111,234	)	$	4,050,202
(1) Reconciliation of segment profit to consolidated profit:	Segment profit								$	165,205
(2) Balances as of December 31, 2011	Unallocated items:
	Preferred dividends requirements								26
	Preferred stock redemption costs								112
	Net income applicable to common stock								$	165,067

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Recent Authoritative Guidance (Policies)

9 Months Ended

Sep. 30, 2012

New Accounting Pronouncements and Changes in Accounting Principles [Abstract]

New Accounting Pronouncements, Policy [Policy Text Block]

In April 2011, FASB issued guidance to improve the accounting for repurchase agreements and other similar agreements. Specifically, this guidance modifies the criteria for determining when these transactions would be accounted for as financings as opposed to sales or purchases with commitments to repurchase or resale. The adoption of this guidance was effective for the first period beginning on or after December 15, 2011. The adoption of this guidance did not have a material impact on the financial condition or results of operations of the Registrants.

In May 2011, FASB issued guidance on fair value measurements. This guidance results in a consistent definition of fair value and common requirements for measurement of and disclosure about fair value between GAAP and International Financial Reporting Standards. The adoption of this guidance is effective prospectively for interim and annual periods beginning after December 15, 2011. The adoption of this guidance did not have a material impact on the financial condition or results of operations of the Registrants.

In December 2011, FASB revised the disclosure requirements related to balance sheet offsetting. After the effective date, entities must disclose both the gross and net information about instruments and transactions eligible for offsetting on the balance sheet, including transactions under master netting agreements. The adoption of this revision is required for interim and annual periods beginning on or after January 1, 2013. The adoption of this revision will not have any effect on the financial condition or results of operations of the Registrants since it relates to disclosures.

In July 2012, FASB issued guidance on testing indefinite-lived intangible assets for impairment. This guidance is intended to reduce costs and complexity of testing indefinite-lived intangible assets other than goodwill for impairment. Entities are allowed to perform a “qualitative” assessment to determine whether further impairment testing of indefinite-lived intangible assets is necessary, similar in approach to the goodwill impairment test. The adoption of this guidance is effective for annual and interim impairment tests performed for fiscal years beginning after September 15, 2012. The adoption of this guidance will not have any impact on the financial condition or results of operations of the Registrants.

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Disclosures about Guarantees (Details) (USD $)								3 Months Ended	9 Months Ended		3 Months Ended		9 Months Ended			3 Months Ended	9 Months Ended
	Sep. 30, 2012	Dec. 31, 2011	Feb. 28, 2010 Guarantee Issued to Cleco Power on behalf of Acadia [Member]	Sep. 30, 2012 Cleco Corporation [Member] Guarantee Issued to Entergy Louisiana and Entergy Gulf States for Performance Obligations of Perryville [Member]	Sep. 30, 2012 Cleco Corporation [Member] Guarantee Issued to Entergy Louisiana on behalf of Acadia [Member]	Sep. 30, 2012 Cleco Power [Member] Lignite Mining Agreement Guarantee [Member]	Feb. 28, 2010 Cleco Power [Member] Acadia Unit 1 Transaction [Member]	Sep. 30, 2011 APH [Member] Acadia Unit 1 Transaction [Member]	Sep. 30, 2012 APH [Member] Acadia Unit 1 Transaction [Member]	Sep. 30, 2011 APH [Member] Acadia Unit 1 Transaction [Member]	Sep. 30, 2012 Acadia Power Partners [Member] Acadia Unit 1 Transaction [Member]	Sep. 30, 2011 Acadia Power Partners [Member] Acadia Unit 1 Transaction [Member]	Sep. 30, 2012 Acadia Power Partners [Member] Acadia Unit 1 Transaction [Member]	Sep. 30, 2011 Acadia Power Partners [Member] Acadia Unit 1 Transaction [Member]	Feb. 23, 2010 Acadia Power Partners [Member] Acadia Unit 1 Transaction [Member]	Sep. 30, 2012 Acadia Power Partners [Member] Acadia Unit 2 Transaction [Member]	Sep. 30, 2012 Acadia Power Partners [Member] Acadia Unit 2 Transaction [Member]	Apr. 29, 2011 Acadia Power Partners [Member] Acadia Unit 2 Transaction [Member]	Apr. 29, 2011 Acadia Power Partners [Member] APH [Member]	Apr. 29, 2011 Cajun [Member] APH [Member]	Sep. 30, 2012 Maximum [Member] Acadia Power Partners [Member] Acadia Unit 1 Transaction [Member]
Disclosures about Guarantees [Abstract]
Liability recognized on the balance sheets	$ 14,356,000			$ 200,000		$ 3,800,000
Term of indemnification obligation											3 years					3 years
Maximum residual value of indemnification obligation																200,000	200,000				100,000
Indemnification liability representing risk of payment	10,350,000	29,357,000									400,000		400,000		13,500,000	10,000,000	10,000,000	21,800,000
Income from contractual expiration of indemnification								0	0	500,000	0	1,000,000	7,200,000	1,100,000		0	11,800,000
Estimated maximum projected payment			10,000,000		298,800,000	72,500,000	30,000,000
Off-balance sheet commitments, expected termination dates [Abstract]
NET AMOUNT COMMITTED	4,225,000			42,400,000
LESS THAN ONE YEAR	3,725,000
1-3 YEARS	0
3-5 YEARS	0
MORE THAN 5 YEARS	500,000
On-balance sheet guarantees, expected termination dates [Abstract]
NET AMOUNT COMMITTED	14,356,000			200,000		3,800,000
LESS THAN ONE YEAR	0
1-3 YEARS	10,350,000
3-5 YEARS	0
MORE THAN 5 YEARS	4,006,000
Total off-balance sheet commitments and on-balance sheet guarantees, expected termination dates [Abstract]
Total NET AMOUNT COMMITTED	18,581,000
Total LESS THAN ONE YEAR	3,725,000
Total 1-3 YEARS	10,350,000
Total 3-5 YEARS	0
Total MORE THAN 5 YEARS	$ 4,506,000
Equity Method Investment, Ownership Percentage																			100.00%
Ownership interest exchanged (in hundredths)																				50.00%

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Consolidated Statements of Cash Flows (USD $) In Thousands, unless otherwise specified	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011
Operating activities
Net income	$ 140,536	$ 165,205
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	122,676	114,104
Return on equity investment in investees	0	58,665
Income from equity investments	(1)	(62,051)
Unearned compensation expense	4,986	6,065
Allowance for other funds used during construction	(4,298)	(3,757)
Net deferred income taxes	8,040	45,336
Deferred fuel costs	(4,218)	(6,422)
Cash surrender value of company-/trust-owned life insurance	(2,841)	1,055
Changes in assets and liabilities:
Accounts receivable	(13,247)	(21,691)
Accounts and notes receivable, affiliate	257	1,074
Unbilled revenue	(1,376)	11,538
Fuel, materials and supplies inventory	(15,943)	40,675
Prepayments	920	2,089
Accounts payable	(25,422)	(37,467)
Customer deposits	8,772	9,718
Postretirement benefit obligations	5,459	(56,743)
Regulatory assets and liabilities, net	(30,532)	(40,204)
Contingent sale obligations	0	10,900
Other deferred accounts	(17,388)	2,181
Taxes accrued	36,021	12,946
Interest accrued	7,616	10,738
Energy risk management assets and liabilities, net	(28)	3,880
Other operating	4,615	(4,244)
Net cash provided by operating activities	224,604	263,590
Investing activities
Additions to property, plant, and equipment	(177,146)	(146,617)
Allowance for other funds used during construction	4,298	3,757
Property plant and equipment grants	15,075	1,593
Insurance reimbursement for casualty loss	5,454	0
Cash from reconsolidation of VIEs	0	3,879
Return of equity investment in investees	0	89,654
Return of investment tax credit fund	37,132	244
Contributions to tax credit fund	(46,859)	(18,479)
Transfer of cash from restricted accounts	19,102	12,144
Purchase of restricted investments	(4,340)	0
Other investing	(1,934)	(1,220)
Net cash provided by (used in) investing activities	(149,218)	(55,045)
Financing activities
Retirement of short-term debt	0	(150,000)
Draws on credit facility	0	10,000
Payments on credit facility	(10,000)	(25,000)
Issuance of long-term debt	50,000	0
Retirement of long-term debt	(74,368)	(12,269)
Repurchase of common stock	(8,007)	(13,009)
Dividends paid on common stock	(58,459)	(49,170)
Other financing	236	(1,993)
Net cash (used in) provided by financing activities	(100,598)	(241,441)
Net (decrease) increase in cash and cash equivalents	(25,212)	(32,896)
Cash and cash equivalents at beginning of period	93,576	191,128
Cash and cash equivalents at end of period	68,364	158,232
Supplementary cash flow information
Interest paid (net of amount capitalized)	48,212	53,936
Income taxes paid, net	(131)	18,241
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	16,657	11,491
Non-cash additions to property, plant, and equipment	18,395	6,252
Issuance of common stock - ESPP	257	241
Cleco Power [Member]
Operating activities
Net income	121,873	119,557
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	102,724	95,482
Income from equity investments	0	0
Unearned compensation expense	1,327	1,768
Allowance for other funds used during construction	(4,298)	(3,757)
Net deferred income taxes	43,259	35,174
Deferred fuel costs	(4,218)	(6,422)
Cash surrender value of company-/trust-owned life insurance	(308)	(277)
Changes in assets and liabilities:
Accounts receivable	(13,807)	(23,859)
Accounts and notes receivable, affiliate	(762)	68
Unbilled revenue	(1,376)	11,538
Fuel, materials and supplies inventory	(15,778)	40,946
Prepayments	614	1,858
Accounts payable	(20,474)	(32,826)
Accounts and notes payable, affiliate	(53)	(1,386)
Customer deposits	8,772	9,718
Postretirement benefit obligations	4,323	(58,259)
Regulatory assets and liabilities, net	(30,532)	(40,204)
Other deferred accounts	(20,057)	(1,996)
Taxes accrued	23,194	21,680
Interest accrued	9,482	11,075
Energy risk management assets and liabilities, net	(28)	3,880
Other operating	1,650	1,878
Net cash provided by operating activities	205,527	185,636
Investing activities
Additions to property, plant, and equipment	(173,268)	(131,962)
Allowance for other funds used during construction	4,298	3,757
Property plant and equipment grants	15,075	1,593
Transfer of cash from restricted accounts	19,102	12,144
Purchase of restricted investments	(4,340)	0
Other investing	804	664
Net cash provided by (used in) investing activities	(138,329)	(113,804)
Financing activities
Issuance of long-term debt	50,000	0
Retirement of long-term debt	(74,368)	(12,269)
Distribution to parent	(58,000)	(100,000)
Other financing	(1,710)	(1,460)
Net cash (used in) provided by financing activities	(84,078)	(113,729)
Net (decrease) increase in cash and cash equivalents	(16,880)	(41,897)
Cash and cash equivalents at beginning of period	67,458	184,912
Cash and cash equivalents at end of period	50,578	143,015
Supplementary cash flow information
Interest paid (net of amount capitalized)	48,140	52,220
Income taxes paid, net	(246)	2,233
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	16,141	20,088
Non-cash additions to property, plant, and equipment	$ 18,395	$ 6,252

XML

Consolidated Statements of Comprehensive Income (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Net income	$ 63,818	$ 65,842	$ 140,536	$ 165,205
Other comprehensive (loss) income, net of tax:
Amortization of postretirement benefit net loss, net of tax	332	269	1,221	910
Net derivative gain (loss), net of tax	493	(18,433)	(451)	(18,433)
Total other comprehensive income (loss), net of tax	815	(18,219)	2,364	(17,687)
Comprehensive income, net of tax	64,633	47,623	142,900	147,518
Interest Expense [Member]
Other comprehensive (loss) income, net of tax:
Reclassification of net (gain) loss, net of tax	(10)	(55)	24	164
Cleco Power [Member]
Net income	57,783	53,833	121,873	119,557
Other comprehensive (loss) income, net of tax:
Amortization of postretirement benefit net loss, net of tax	124	146	555	519
Net derivative gain (loss), net of tax	493	(18,433)	(451)	(18,433)
Total other comprehensive income (loss), net of tax	607	(18,342)	1,698	(18,078)
Comprehensive income, net of tax	58,390	35,491	123,571	101,479
Cleco Power [Member] | Interest Expense [Member]
Other comprehensive (loss) income, net of tax:
Reclassification of net (gain) loss, net of tax	(10)	(55)	24	(164)
Regulatory Asset [Member]
Other comprehensive (loss) income, net of tax:
Reclassification of ineffectiveness to regulatory asset, net of tax			1,570	0
Regulatory Asset [Member] | Cleco Power [Member]
Other comprehensive (loss) income, net of tax:
Reclassification of ineffectiveness to regulatory asset, net of tax			$ 1,570	$ 0

XML

Variable Interest Entities

9 Months Ended

Sep. 30, 2012

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.

Prior to April 30, 2011, Cleco Corporation also reported its investment in Cajun on the equity method of accounting. In conjunction with the disposition of Acadia Unit 2, APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH.

Consolidated VIEs

Acadia

In October 2009, Acadia and Entergy Louisiana announced that definitive agreements had been executed whereby Entergy Louisiana would acquire Acadia Unit 2.  On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 to Entergy Louisiana for $298.8 million. Following the disposition, Acadia no longer owns any materials and supply inventory, property, plant, and equipment, or land. Following the transaction, ongoing operations at Acadia are minimal, relating only to the previously established accounts receivable, accounts payable, and servicing indemnifications which Cleco assumed in the transaction. In conjunction with the transaction, APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH. For more information on the Acadia Unit 2 transaction, see Note 13 — “Acadia Unit 2 Transaction.”

The following table contains summarized financial information for Cajun prior to the disposition of Acadia Unit 2.

(THOUSANDS)	FOR THE NINE MONTHS ENDED SEPT. 30, 2011*
Operating revenue		$	5,227
Operating expenses		5,914
Gain on sale of assets		71,422
Other income		929
Income before taxes		$	71,664
*The 2011 income statement includes only activity through the April 29, 2011, reconsolidation.

Prior to the reconsolidation, income tax expenses related to Cajun were recorded on APH’s financial statements. For the four months ended April 30, 2011, income tax expenses related to Cajun on APH’s financial statements were $24.0 million.

Equity Method VIEs

Equity investment in investees at September 30, 2012, primarily represented Cleco Power’s $14.5 million investment in Oxbow. Equity investments which are less than 100% owned by Cleco Innovations LLC represented less than $0.1 million of the total balance.

The following table presents the equity income (loss) from each investment accounted for using the equity method.  

	FOR THE THREE MONTHS ENDED SEPT. 30,					FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011			2012		2011
Cajun	$	—	$	—		$	—	$	62,053
Subsidiaries less than 100% owned by Cleco Innovations	—		(1		)	1		(2		)
Total equity (loss) income	$	—	$	(1	)	$	1	$	62,051

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 September 30, 2012, 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 SEPT. 30, 2012		AT DEC. 31, 2011
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 SEPT. 30, 2012		AT DEC. 31, 2011
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 SEPT. 30, 2012		AT DEC. 31, 2011
Current assets	$	1,753	$	1,711
Property, plant, and equipment, net	23,119		23,339
Other assets	4,247		4,128
Total assets	$	29,119	$	29,178
Current liabilities	$	24	$	40
Other liabilities	30		73
Partners’ capital	29,065		29,065
Total liabilities and partners’ capital	$	29,119	$	29,178

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
Operating revenue	$	450	$	382	$	1,125	$	880
Operating expenses	450		382		1,125		880
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.

XML

Document And Entity Information	9 Months Ended
	Sep. 30, 2012	Oct. 26, 2012
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	Sep. 30, 2012
Document Fiscal Year Focus	2012
Document Fiscal Period Focus	Q3
Amendment Flag	false
Entity Common Stock, Shares Outstanding		60,726,390
Cleco Power [Member]
Entity Information [Line Items]
Entity Registrant Name	CLECO POWER LLC
Entity Central Index Key	0000018672
Entity Filer Category	Non-accelerated Filer

XML

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees

9 Months Ended

Sep. 30, 2012

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 potentially responsible parties (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 has identified Cleco as one of many companies sending PCB wastes for disposal to the site. The Devil’s Swamp Lake site has been proposed to be added to the National Priorities List (NPL) based on the release of PCBs to fisheries and wetlands located on the site. The EPA has yet to make a final determination on whether to add Devil’s Swamp Lake site to the NPL. The PRPs began discussing a potential proposal to the EPA in February 2008 and since that time, Cleco is unaware of any progress made in regard to the RI/FS negotiations. 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

On December 11, 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 is seeking various remedies provided under applicable statutes prohibiting racial discrimination in the workplace, and together, the plaintiffs seek monetary compensation exceeding $35.0 million. On July 29, 2010, the plaintiffs moved to add an additional current employee alleging that Cleco had discriminated on the basis of race. The additional plaintiff seeks compensation of no less than $2.5 million and became the 13th plaintiff. On April 13, 2011, Cleco entered into a settlement with one of the current employees which resulted in a dismissal of one of the 13 cases with prejudice. In September 2011, the Court ruled on Cleco’s summary judgment motions. The judge granted and denied the motions in part, with the end result that 11 out of 12 of the remaining plaintiffs have at least one claim remaining. The Court has severed the cases of the 11 remaining plaintiffs for further proceedings, and, if necessary, the trial. Additional depositions were completed in February 2012, and Cleco filed a summary judgment motion in each of the remaining 11 cases on March 8, 2012. Each of such motions was fully briefed and submitted for decision by May 11, 2012. None of these cases has been set for trial and likely will not be set until the Court rules on Cleco’s motions for summary judgment.

On July 31, 2012, nine of the eleven plaintiffs in the pending discrimination suits described above filed a new lawsuit in the same federal court in Shreveport alleging that Cleco and its Chief Executive Officer retaliated against them for pursuing their discrimination claims by directly writing them an offer of settlement that contained allegedly intimidating threats. The nine plaintiffs consist of six current employees and three former employees. The plaintiffs filed an amended complaint on August 29, 2012, stating that such settlement letters were delivered to legal counsel for each of the plaintiffs and not directly to the plaintiffs. On September 6, 2012, Cleco filed a motion to dismiss the lawsuit. The basis of such motion is Cleco's argument that statements made in an offer of settlement cannot constitute retaliation and give rise to damages pursuant to judicial policies favoring settlement. Otherwise Cleco argues that the amended complaint fails to state a cause of action upon which relief can be granted.

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.

City of Opelousas

On March 9, 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. Cleco Power currently operates in Opelousas pursuant to a franchise granted to Cleco Power by the City of Opelousas in 1986 and an operating and franchise agreement dated May 14, 1991, pursuant to which Cleco Power operates its own electric facilities and leases and operates electric facilities owned by the City of Opelousas. 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 addition, Cleco Power removed the purported class action lawsuit filed on behalf of Opelousas electric customers from the state court to the U.S. District Court for the Western District of Louisiana in April 2010, so that it could be properly addressed under the terms of the Class Action Fairness Act. On May 11, 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. Cleco Power has responded in the same manner as with the first class action lawsuit. In September 2010, the federal court remanded both cases to the state court in which they were originally filed for further proceedings. 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 November 2011, the Louisiana Supreme Court granted the appeals and remanded the case to the Third Circuit for further briefing, argument, and opinion. 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. On January 30, 2012, the class action plaintiffs filed their appeal of such LPSC decision to the 19th Judicial District Court for Baton Rouge Parish, State of Louisiana. On February 15, 2012, the Third Circuit ruled that the state court, and not the LPSC, has jurisdiction to hear the case. On March 15, 2012, Cleco Power appealed the Third Circuit’s ruling to the Louisiana Supreme Court asking that it overturn the Third Circuit decision and confirm the LPSC’s exclusive jurisdiction over this matter. The LPSC also appealed the Third Circuit’s ruling to the Louisiana Supreme Court in March 2012. On May 18, 2012, the Louisiana Supreme Court granted the writ application of Cleco Power and the LPSC and set the matter for further briefing on the merits of the jurisdiction question raised in the writ application. Such briefing was completed during the third quarter of 2012 and the Louisiana Supreme Court heard oral arguments on September 7, 2012. A decision from the Louisiana Supreme Court is expected during the fourth quarter of 2012. 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.

LPSC Audits

Fuel Audit

The cost of fuel used for electric generation and the cost of power purchased for utility customers are recovered through an LPSC-established fuel adjustment clause that enables Cleco Power to pass on to its customers substantially all such charges. The LPSC Fuel Adjustment Clause General Order issued November 6, 1997, in Docket No. U-21497 provides that an audit of fuel adjustment clause filings will be performed not less than every other year. In March 2009, the LPSC initiated an audit of fuel adjustment clause filings for the years 2003 through 2008. The total amount of fuel expenses included in the audit was approximately $3.26 billion. In February 2012, the LPSC Staff’s consultant issued a preliminary audit report recommending a cost disallowance of approximately $0.4 million plus interest for these filing years. There was no opposition from intervenors to the recommendations of the LPSC Staff’s consultant and the report was approved by the LPSC on July 18, 2012. Cleco Power made refunds of $0.4 million plus interest to customers during the September 2012 billing cycle. Cleco Power has fuel adjustment clause filings for the years 2009 through 2011 that remain subject to audit.

Environmental Audit

In July 2009, the LPSC issued Docket No. U-29380 Subdocket A, which provides for an environmental adjustment clause to recover certain costs of environmental compliance as an adder to customers’ bills. The costs eligible for recovery are prudently incurred air emissions credits associated with complying with federal, state, and local air emission regulations that apply to the generation of electricity reduced by the sale of such allowances. Also eligible for recovery are variable emission mitigation costs, which are the cost of reagents such as ammonia and limestone that are used to reduce air emissions. In November 2011, the LPSC initiated an audit of the costs for the period October 2009 through October 2010. The total amount of environmental expenses included in the audit was approximately $11.3 million. In April 2012, the LPSC Staff’s consultant issued a preliminary audit report recommending no cost disallowance for the review period. There was no opposition from intervenors to the recommendations of the LPSC Staff’s consultant and the report was approved by the LPSC on July 18, 2012. Cleco Power has environmental adjustment clause filings for the years 2010 through 2012 that remain subject to audit.

Other

Cleco is involved in various litigation matters, including regulatory, environmental, and administrative proceedings before various courts, regulatory commissions, arbitrators, and governmental agencies regarding matters arising in the ordinary course of business. The liability Cleco may ultimately incur with respect to any one of these matters in the event of a negative outcome may be in excess of amounts currently accrued. Management regularly analyzes current information and, as of September 30, 2012, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters is approximately $2.5 million.

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 also have 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 September 30, 2012, 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 SEPT. 30, 2012
(THOUSANDS)	FACE AMOUNT		REDUCTIONS		NET AMOUNT
Cleco Corporation
Guarantee issued to Entergy Mississippi on behalf of Attala	$	500	$	—	$	500
Cleco Power
Obligations under standby letter of credit issued to the Louisiana Department of Labor	3,725		—		3,725
Total	$	4,225	$	—	$	4,225

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 through the life of the agreement.

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.

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 September 30, 2012, 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 February 2010, Cleco Power acquired Acadia Unit 1 and half of Acadia Power Station’s related common facilities. Acadia provided limited guarantees and indemnifications to Cleco Power under the Master Reorganization and Redemption Agreement. The maximum amount of the potential payment to Cleco Power for indemnifications is $30.0 million, except for the indemnifications relating to the fundamental organizational structure of Acadia against which there is no maximum amount. Cleco Corporation is obligated to pay a maximum of $10.0 million if Acadia is unable to pay claims to Cleco Power pursuant to the guarantee. Acadia recorded an indemnification liability of $13.5 million which represents the fair value of these indemnifications.

Acadia and APH will reduce the indemnification liabilities either 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 approximately three years. After the three-year period, a residual value of less than $0.1 million will remain. At September 30, 2012, Acadia had an indemnification liability of approximately $0.4 million remaining, which represents the risk of payment, as a contingent sale obligation recorded on Cleco’s Condensed Consolidated Balance Sheet. APH recognized no income for the three and nine months ended September 30, 2012, and no income for the three months ended September 30, 2011, and $0.5 million for the nine months ended September 30, 2011, respectively, primarily due to the contractual expiration of the underlying indemnifications. Acadia recognized no income for the three months ended September 30, 2012, and income of $7.2 million for the nine months ended September 30, 2012, primarily due to the contractual expiration of the underlying indemnifications. During the three and nine months ended September 30, 2011, Acadia recognized income of $1.0 million and $1.1 million, respectively, primarily due to the contractual expiration of the underlying indemnifications.

On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 and Acadia Power Station’s remaining common facilities to Entergy Louisiana. Acadia provided limited guarantees and indemnifications to Entergy Louisiana and recorded an indemnification liability of $21.8 million, which represents the fair value of these indemnifications. In conjunction with the disposition of Acadia Unit 2, APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH.

Acadia and APH will reduce the indemnification liabilities either 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 September 30, 2012, Acadia had an indemnification liability of $10.0 million remaining, which represents the risk of payment, as a contingent sale obligation recorded on Cleco’s Condensed Consolidated Balance Sheet. Acadia recognized no income for the three months ended September 30, 2012, and $11.8 million for the nine months ended September 30, 2012, primarily due to the contractual expiration of the underlying indemnifications. 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 by Acadia, 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 lignite miner’s loan and lease principal obligations when due, if the lignite miner does not have sufficient funds or credit to pay. Any amounts paid on behalf of the miner would be credited by the lignite miner against the next invoice for lignite delivered. At September 30, 2012, 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 $72.5 million; however, the Amended Lignite Mining Agreement does not contain a cap. The projection is based on the forecasted loan and lease obligations to be incurred by DHLC, primarily for purchases of equipment. Cleco Power has the right to dispute the incurrence of loan and lease obligations through the review of the mining plan before the incurrence of such loan and lease obligations. The Amended Lignite Mining Agreement does not terminate pursuant to its terms until 2026 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 termination dates of the off-balance sheet commitments and on-balance sheet guarantees discussed above.

							AT SEPT. 30, 2012
			AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
(THOUSANDS)	NET AMOUNT COMMITTED		LESS THAN ONE YEAR		1-3 YEARS		3-5 YEARS		MORE THAN 5 YEARS
Off-balance sheet commitments	$	4,225	$	3,725	$	—	$	—	$	500
On-balance sheet guarantees	14,356		—		10,350		—		4,006
Total	$	18,581	$	3,725	$	10,350	$	—	$	4,506

Other Commitments

New Markets Tax Credits

In 2008, Cleco Corporation and US Bancorp Community Development (USBCDC) formed the NMTC Fund. Cleco has a 99.9% membership interest in the NMTC Fund and USBCDC has a 0.1% interest in the NMTC Fund. The purpose of the NMTC Fund is to invest in projects located in qualified active low-income communities that are underserved by typical debt capital markets. These investments are designed to generate New Markets Tax Credits 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 American Recovery and Reinvestment Tax Act of 2009. The tax benefits received from the NMTC Fund reduce the federal income tax obligations of Cleco Corporation. In total, Cleco Corporation will contribute $285.5 million of equity contributions to the NMTC Fund and will receive at least $303.8 million in the form of tax credits, tax losses, capital gains/losses, earnings and cash over the life of the investment, which ends in 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
Three months ending Dec. 31, 2012	$	12,786
Years ending Dec. 31,
2013	50,822
2014	39,059
2015	12,975
2016	11,890
2017	3,292
Total	$	130,824

Of the $130.8 million, $51.6 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 September 30, 2012, was $104.7 million. The amount of tax benefits delivered but not utilized as of September 30, 2012, was $86.5 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:	$	130,824
Less:  unamortized discount	12,291
Total	$	118,533

The gross investment amortization expense will be recognized over a ten-year period, with five years remaining under the new amendment, using the cost method in accordance with the authoritative guidance for investments. The grants received under Section 1603 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.

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. After assessing the current operating performance, liquidity, and credit ratings of Cleco Corporation, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. If Cleco Corporation’s credit ratings were to be downgraded by Moody’s and Standard & Poor’s, 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 supplies the majority of its customers’ electric power requirements from its own generation facilities. In addition to power obtained from power purchase agreements, Cleco Power purchases power from other utilities and marketers to supplement its generation at times of relatively high demand or when the purchase price of power is less than its own cost of generation. Due to its location on the transmission grid, Cleco Power relies on two main suppliers of electric transmission when accessing external power markets. At times, constraints limit the amount of purchased power these transmission providers can deliver into Cleco Power’s service territory.

Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows. After assessing the current operating performance, liquidity, and credit ratings of Cleco Power, management believes that Cleco Power will have access to the capital markets at prevailing market rates for companies with comparable credit ratings. 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 and Standard & Poor’s, 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 Standard & Poor’s, Cleco Power would be required to pay additional collateral for derivatives.

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Consolidated Statements of Comprehensive Income (Parenthetical) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011
Other comprehensive income (loss), net of tax:
Net tax expense (benefit) of amortization of postretirement benefit net (loss) gain	$ 239	$ 178	$ 670	$ 454
Cash flow hedges:
Net tax (benefit) expense of net derivative (loss) gain	309	(11,529)	(282)	(11,529)
Interest Expense [Member]
Cash flow hedges:
Net tax (benefit) expense of reclassification of net gain (loss)	(7)	(34)	15	(103)
Cleco Power [Member]
Other comprehensive income (loss), net of tax:
Net tax expense (benefit) of amortization of postretirement benefit net (loss) gain	103	99	267	227
Cash flow hedges:
Net tax (benefit) expense of net derivative (loss) gain	309	(11,529)	(282)	(11,529)
Cleco Power [Member] | Interest Expense [Member]
Cash flow hedges:
Net tax (benefit) expense of reclassification of net gain (loss)	(7)	(34)	15	(103)
Regulatory Asset [Member]
Cash flow hedges:
Net tax (benefit) expense of reclassification of ineffectiveness to regulatory asset	0	0	982	0
Regulatory Asset [Member] | Cleco Power [Member]
Cash flow hedges:
Net tax (benefit) expense of reclassification of ineffectiveness to regulatory asset	$ 0	$ 0	$ 982	$ 0

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Debt

9 Months Ended

Sep. 30, 2012

Debt Disclosure [Abstract]

Debt

Note 5 — Debt

Short-term Debt

At September 30, 2012 and December 31, 2011, Cleco and Cleco Power had no short-term debt outstanding.

Long-term Debt

At September 30, 2012, Cleco and Cleco Power's long-term debt outstanding was $1.33 billion, of which $90.9 million was due within one year. The long-term debt due within one year at September 30, 2012, represents $75.0 million in senior notes due May 1, 2013, $14.0 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $1.9 million of capital lease payments. For Cleco, long-term debt decreased$33.2 million from December 31, 2011, primarily due to Cleco Power redeeming $50.1 million of DeSoto Parish pollution control bonds in May 2012 and $11.2 million of Rapides Parish pollution control bonds in January 2012. Also contributing to the decrease was a $10.0 million reduction in Cleco Corporation's credit facility draws, and $13.1 million of scheduled Cleco Katrina/Rita storm recovery bond principal payments made in March and September 2012. These decreases were partially offset by Cleco Power’s issuance of $50.0 million of senior notes in May 2012, $0.5 million of capital lease payments and debt premium amortizations of $0.7 million.

On January 25, 2012, Cleco Power redeemed at par $11.2 million of 5.875% Rapides Parish pollution control bonds due September 2029. As part of the redemption, Cleco Power paid $0.3 million of accrued interest on the redeemed notes.

On May 8, 2012, Cleco Power issued $50.0 million senior unsecured private placement notes at an interest rate of 4.33%.  The maturity date of the notes is May 15, 2027.  The proceeds were used primarily for the early redemption of $50.1 million of 5.875% DeSoto Parish pollution control bonds.

On May 11, 2012, Cleco Power redeemed at par all $50.1 million of 5.875% DeSoto Parish pollution control bonds due September 2029. As part of the redemption, Cleco Power paid $0.6 million of accrued interest on the redeemed notes.

Credit Facilities

At September 30, 2012, Cleco Corporation and Cleco Power had no borrowings outstanding under their respective existing credit facilities.

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Fair Value Accounting

9 Months Ended

Sep. 30, 2012

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 September 30, 2012 and December 31, 2011, for cash and cash equivalents, restricted cash and cash equivalents, accounts receivable, other accounts receivable, accounts payable, and short-term debt approximate fair value because of their short-term nature.  Estimates of the fair value of Cleco and Cleco Power’s long-term debt are based upon the quoted market price for the same or similar issues or by a discounted present value analysis of future cash flows using current rates obtained by Cleco and Cleco Power for debt with similar maturities. The following tables summarize the carrying value and estimated market value of Cleco and Cleco Power’s financial instruments subject to fair value accounting.

Cleco
	AT SEPT. 30, 2012				AT DEC. 31, 2011
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market
Cash and cash equivalents	$	68,364	$	68,364	$	93,576	$	93,576
Restricted cash and cash equivalents	$	16,726	$	16,726	$	35,828	$	35,828
Long-term debt, excluding debt issuance costs	$	1,320,198	$	1,553,694	$	1,354,567	$	1,542,867

Cleco Power
	AT SEPT. 30, 2012				AT DEC. 31, 2011
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market
Cash and cash equivalents	$	50,578	$	50,578	$	67,458	$	67,458
Restricted cash and cash equivalents	$	16,629	$	16,629	$	35,731	$	35,731
Long-term debt, excluding debt issuance costs	$	1,320,198	$	1,553,694	$	1,344,567	$	1,532,867

At September 30, 2012, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents and restricted cash equivalents. Cleco had $74.7 million ($58.5 million of cash equivalents and $16.2 million of restricted cash equivalents) in short-term investments in institutional money market funds. Cleco Power had $61.1 million ($45.0 million of cash equivalents and $16.1 million of restricted cash equivalents) in short-term investments in institutional money market funds. 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.

In May 2012, Cleco and Cleco Power revised their guidelines for short-term investments in order to mitigate credit risk. Qualifying investments include:

• U.S. treasury securities,

• U.S. federal agency and U.S. government-sponsored entity debt,

• Tax-exempt short-term securities of a state, territory, or a possession of the U.S.,

• Certificates of deposit, banker's acceptances and time deposits,

• Corporate notes and bonds, fixed or floating rate, and covered bonds,

• Commercial paper,

• Asset backed securities with a minimum long-term rating of AA by Standard & Poor's and Aaa by Moody's,

• U.S. government mortgage securities with a short average life with a minimum long-term rating of AA by Standard & Poor's and Aaa by Moody's,

• Repurchase agreements with the primary government securities dealers or financial institutions in which Cleco deposits and/or concentrates cash, and

• Money market funds which must have at least $15.0 billion in assets under management; must have been in existence for not less than two years; must have a minimum rating of AAA by Standard & Poor's and Aaa by Moody's and must be compliant with the SEC rule 2a-7 which restricts the quality, maturity, and diversity of investments by money market funds.

The minimum acceptable short-term credit rating must be A-1 by Standard & Poor's and P-1 by Moody's. The maximum maturity of any instrument must be 36 months, and the maximum portfolio duration must be 12 months.

Diversification of holdings must be stressed recognizing the total amount of the portfolio. Investments in securities of any one issuer will be limited to 5% at the time of purchase except for U.S. Treasury and Agency Securities and money market funds. No more than 50% of the portfolio at the time of purchase will be invested in any single Federal Agency/Government Sponsored Enterprise.

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 are restricted to the criteria established by management in Cleco Power's guidelines for short-term investments. At September 30, 2012, the investments included institutional money market funds and municipal bonds.

The institutional money market fund investments are reflected in Cleco and Cleco Power's Condensed Consolidated Balance Sheets at September 30, 2012, as restricted cash and cash equivalents and approximate fair value because of their short-term nature. 

The municipal bonds were recorded at fair value on Cleco and Cleco Power's Condensed Consolidated Balance Sheets at September 30, 2012, as restricted investments. The investments in municipal bonds are classified as available-for-sale securities and are marked-to-market at least quarterly. Because Cleco Power's investment strategy for these investments fits 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 are recorded directly to Cleco Power's restricted storm reserve rather than in earnings or other comprehensive income. As a result no amounts will be recorded to other comprehensive income for these investments.

Quarterly, Cleco Power's available-for-sale, debt securities are evaluated on an individual basis to determine if a decline in fair value below the carrying value is other-than-temporary. Management determines whether it intends to sell or if it is more likely than not that it will be required to sell impaired securities. This determination considers current and forecasted liquidity and regulatory requirements. For Cleco Power's impaired debt securities for which there was no intent or expected requirement to sell, the evaluation assesses whether it is likely the amortized cost will be recovered considering the nature of the securities, credit rating, financial condition of the issuer or the extent and duration of the unrealized loss and market conditions. If Cleco Power determined that an other-than-temporary decline in value existed on its municipal bonds, the investments would be written down to fair value with a new cost basis established. Declines in fair value below cost basis that are determined to be other-than-temporary would be recorded to Cleco Power's restricted storm reserve. The unrealized losses on Cleco Power's municipal bonds as of September 30, 2012, were caused by interest rate movements. Cleco Power does not intend to sell the municipal bonds and has determined it is more likely than not that it will not be required to sell the investments before recovery of the amortized cost value. Cleco Power determined there were no material other-than-temporary impairments on its municipal bonds at September 30, 2012.

The following table provides a reconciliation of Cleco Power's available-for-sale securities from cost basis to fair value at September 30, 2012.

	AT SEPT. 30, 2012
(THOUSANDS)	AMORTIZED COST		TOTAL UNREALIZED GAINS (1)		TOTAL UNREALIZED LOSSES (1)		FAIR VALUE
Municipal bonds	$	4,477	$	2	$	9	$	4,470
(1)  Unrealized gains and losses are recorded to the restricted storm reserve.

Cleco Power recognized less than $0.1 million of unrealized mark-to-market losses in the restricted storm reserve for both the three and nine months ended September 30, 2012. The following table summarizes the securities that were in an unrealized loss position at September 30, 2012, but for which no other-than-temporary impairment was recognized:

			LESS THAN 12 MONTHS		12 MONTHS OR LONGER
(THOUSANDS)	AGGREGATE UNREALIZED LOSS		AGGREGATE RELATED FAIR VALUE		AGGREGATE UNREALIZED LOSS		AGGREGATE RELATED FAIR VALUE
Municipal bonds	$	9	$	3,381	$	—	$	—

At September 30, 2012, the fair value of Cleco Power's available-for-sale securities by contractual maturity was:

(THOUSANDS)	AT SEPT. 30, 2012
One year or less	$	1,022
Over one year through five years	3,448
Total fair value	$	4,470

There were no realized gains or losses on Cleco Power's available-for-sale securities during the three and nine months ended September 30, 2012 and 2011. Realized gains and losses will be determined on a specific identification basis.

Interest Rate Derivatives

Forward Starting Interest Rate Swap

On November 14, 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 a $50.0 million fixed-rate forecasted debt issuance. The forward starting interest rate swap has 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 is earlier. The forward starting interest rate swap meets the criteria of a cash flow hedge under the authoritative guidance as it relates to derivatives and hedging and is carried on the balance sheet at its fair value. The fair market value of the forward starting interest rate swap is the difference between the present value of the fixed payments to be paid by Cleco Power and the present value of the three-month LIBOR payments to be received by Cleco Power. Since future LIBOR rates are not available for each month until termination, quoted LIBOR rates from an active exchange for observable time periods were used to create a forward LIBOR curve for all months until termination. Because of the inputs and common techniques used to calculate fair value, the swap valuation was considered Level 2. Cleco Power recognized $0.8 million unrealized mark-to-market gains and $0.7 million unrealized mark-to-market losses in other comprehensive income for the three and nine months ended September 30, 2012, respectively. The fair market value of $4.1 million and $3.3 million for the forward starting interest rate swap was recorded on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets as an interest rate risk management liability as of September 30, 2012 and December 31, 2011, respectively. There was no impact to earnings due to ineffectiveness for the three and nine months ended September 30, 2012.

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 SEPT. 30, 2012		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2011		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Institutional money market funds	$	74,712	$	—	$	74,712	$	—	$	118,951	$	—	$	118,951	$	—
Municipal bonds	$	4,470	$	—	$	4,470	$	—	$	—	$	—	$	—	$	—
Total assets	$	79,182	$	—	$	79,182	$	—	$	118,951	$	—	$	118,951	$	—
Liability Description
Energy market derivatives	$	—	$	—	$	—	$	—	$	5,336	$	—	$	5,336	$	—
Interest rate derivatives	4,063		—		4,063		—		3,330		—		3,330		—
Long-term debt	1,553,694		—		1,553,694		—		1,542,867		—		1,542,867		—
Total liabilities	$	1,557,757	$	—	$	1,557,757	$	—	$	1,551,533	$	—	$	1,551,533	$	—

Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2012		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2011		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)
Asset Description
Institutional money market funds	$	61,115	$	—	$	61,115	$	—	$	99,955	$	—	$	99,955	$	—
Municipal bonds	$	4,470	$	—	$	4,470	$	—	$	—	$	—	$	—	$	—
Total assets	$	65,585	$	—	$	65,585	$	—	$	99,955	$	—	$	99,955	$	—
Liability Description
Energy market derivatives	$	—	$	—	$	—	$	—	$	5,336	$	—	$	5,336	$	—
Interest rate derivatives	4,063		—		4,063		—		3,330		—		3,330		—
Long-term debt	1,553,694		—		1,553,694		—		1,532,867		—		1,532,867		—
Total liabilities	$	1,557,757	$	—	$	1,557,757	$	—	$	1,541,533	$	—	$	1,541,533	$	—

The derivative assets and liabilities are classified as either current or non-current depending on when the positions close. All energy market derivative current assets and current liabilities are reported as a net current energy risk management asset or liability. All energy market derivative non-current assets and non-current liabilities are reported net in other deferred charges or other deferred credits. Net presentation is appropriate due to the right of offset included in the master netting agreements. On the balance sheet, the net current and net non-current derivative positions are netted with the applicable margin deposits.

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 in the amounts of $58.5 million, $3.4 million, and $12.8 million, respectively, at September 30, 2012. 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 and were $45.0 million, $3.4 million, and $12.7 million, respectively, as of September 30, 2012.

The municipal bonds were reported on Cleco and Cleco Power's Condensed Consolidated Balance Sheets in restricted investments in the amount of $4.5 million at September 30, 2012.

The forward starting interest rate swap was reported on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets as a current liability in the line item interest rate risk management liability as of September 30, 2012.

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 for assets and liabilities are determined by obtaining the closing price from published indices in active markets for instruments that are similar to Cleco’s assets and liabilities. The fair value obtained is then discounted to the current period using a U.S. Treasury published interest rate as a proxy for a risk-free rate of return. For some options, Cleco uses the Black-Scholes model using observable and available inputs to calculate the fair value, consistent with the income approach. These techniques have been applied consistently from fiscal period to fiscal period. Level 3 fair values allow for situations in which there is little, if any, market activity for the asset or liability at the measurement date. Cleco had no Level 3 assets or liabilities at September 30, 2012 or December 31, 2011.

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.

Level 2 of energy market derivative assets and liabilities consists of two classes. The first class contains natural gas swaps which fluctuate in value as the underlying natural gas futures fair value changes, and as market interest rates change. Cleco records the mark-to-market value of the natural gas swaps at the net present value. The second class consists of natural gas options. The fair value of natural gas options fluctuates with the volatility in the fair value of natural gas, the number of days until the options expire, the underlying natural gas futures price fluctuations, and market interest rates. Cleco records the mark-to-market value of the natural gas options at the net present value. Both of these energy market derivative classes also contain counterparty execution risk because the transactions are entered into with a direct counterparty and are not traded through an exchange.

The Level 2 institutional money market funds asset consists of a single class. In order to capture interest income and minimize risk, cash is invested in money market funds that invest primarily in short-term securities issued by the U.S. Treasury 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 Level 2 municipal bonds consisted of a single class. In order to maximize income and to meet the requirements established by the LPSC for the restricted reserve fund, restricted cash and cash equivalents were invested in short-term, fixed-income, debt instruments in order to maintain safety and liquidity. The risks associated with this class are counterparty risk of the fund manager and risk of price volatility associated with the municipal bonds. Quarterly, Cleco receives reports from the trustee for the investment manager which provides the fair value measurement. Cleco performs an evaluation of those reports to verify the fair value of the securities.

The Level 2 interest rate derivative was one forward starting interest rate swap liability that consisted of a single class that only contains one instrument. The risks are changes in the three-month LIBOR rate and counterparty risk. This instrument is with a direct counterparty and not traded through an exchange.

The Level 2 long-term debt liability consists of a single class. In order to fund capital requirements, Cleco issues long-term, fixed rate debt with various tenors. The fair value of this class fluctuates as the market interest rates for fixed rate debt with similar tenors and credit ratings changes. 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.

Cleco has a policy which states that transfers between Levels 1, 2, and 3 are recognized at the end of a reporting period. During the nine months ended September 30, 2012, and the year ended December 31, 2011, Cleco did not experience any transfers between levels.

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.

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 as of September 30, 2012 and December 31, 2011.

	DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
	LIABILITY DERIVATIVES
(THOUSANDS) FAIR VALUE	BALANCE SHEET  LINE ITEM	AT SEPT. 30, 2012		AT DEC. 31, 2011
Commodity contracts
Fuel cost hedges:
Current	Energy risk management liability, net	$	—	$	(5,336	)
Total		$	—	$	(5,336	)

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 and nine months ended September 30, 2012 and 2011.

	FOR THE THREE MONTHS ENDED SEPT. 30,								FOR THE NINE MONTHS ENDED SEPT. 30,
		2012			2011				2012			2011
(THOUSANDS)	LOSS IN  INCOME OF DERIVATIVES  LINE ITEM	AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			LOSS IN  INCOME OF DERIVATIVES  LINE ITEM	AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES			AMOUNT OF LOSS RECOGNIZED IN INCOME ON DERIVATIVES
Commodity contracts
Fuel cost hedges(1)	Fuel used for electric generation	$	(595	)	$	(5,678	)	Fuel used for electric generation	$	(8,210	)	$	(14,675	)
Total		$	(595	)	$	(5,678	)		$	(8,210	)	$	(14,675	)
(1)In accordance with the authoritative guidance for regulated operations, no unrealized gains or losses and $0.1 million of deferred losses associated with fuel cost hedges are reported in Accumulated Deferred Fuel on the balance sheet as of September 30, 2012, compared to $5.3 million of unrealized losses and $1.2 million of deferred losses associated with fuel cost hedges as of December 31, 2011. As gains and losses are realized in future periods, they will be recorded as Fuel Used for Electric Generation on the income statement.

At September 30, 2012, Cleco Power had no open positions hedged for natural gas fuel costs. At December 31, 2011, Cleco Power had 2.2 million MMBtus hedged or approximately 3% of gas requirements for a two-year period.

The following tables present the effect of derivatives designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2012 and 2011.

						FOR THE THREE MONTHS ENDED SEPT. 30,
	2012					2011
(THOUSANDS)	AMOUNT OF GAIN RECOGNIZED IN OCI		AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)			AMOUNT OF LOSS RECOGNIZED IN OCI			AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)
Interest rate derivatives	$	802	$	17	*	$	(29,962	)	$	89	*
* The gain (loss) reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.

							FOR THE NINE MONTHS ENDED SEPT. 30,
	2012						2011
(THOUSANDS)	AMOUNT OF LOSS  RECOGNIZED IN OCI			AMOUNT OF LOSS RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)			AMOUNT OF LOSS RECOGNIZED IN OCI			AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)
Interest rate derivatives(1)	$	(733	)	$	(39	)*	$	(29,962	)	$	267	*
* The (loss) gain reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.
(1) During the nine months ended September 30, 2012, Cleco recorded $2.6 million of ineffectiveness related to the interest rate derivatives as a regulatory asset.

At September 30, 2012, Cleco Power expected $0.4 million of the effective portion of deferred net losses related to interest rate derivatives to be reclassed from accumulated OCI to an increase in interest charges over the next 12 months.

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Summary of Significant Accounting Policies (Policies)

9 Months Ended

Sep. 30, 2012

Accounting Policies [Abstract]

Principles of Consolidation

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 Accounting, Policy

Basis of Presentation

The condensed consolidated financial statements of Cleco Corporation and Cleco Power have been prepared pursuant to the rules and regulations of the SEC. Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted; however, Cleco believes that the disclosures are adequate to make the information presented not misleading.

The year-end condensed consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by GAAP. The unaudited financial information included in the condensed consolidated financial statements of Cleco Corporation and Cleco Power reflects all adjustments of a normal recurring nature which are, in the opinion of the management of Cleco Corporation and Cleco Power, necessary for a fair statement of the financial position and the results of operations for the interim periods. Information for interim periods is affected by seasonal variations in sales, rate changes, timing of fuel expense recovery, and other factors, and is not indicative necessarily of the results that may be expected for the full fiscal year. 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

Property, plant, and equipment consist 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

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.

Fair Value Measurements and Disclosures

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. Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the condensed consolidated balance sheets with their fair values as of the balance sheet date disclosed within the three levels. For more information about fair value levels, see Note 4 — “Fair Value Accounting.”

Risk Management

Risk Management

Market risk inherent in Cleco Power’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power and natural gas 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 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 enter into positions 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. When these positions close, actual gains or losses will be included in the fuel adjustment clause and reflected on customers’ bills as a component of the fuel cost adjustment.

Cleco Power maintains margin accounts with commodity brokers used to partially fund the acquisition of natural gas futures, options, and swap contracts. These contracts/positions are used to mitigate the risks associated with the volatility in customer fuel costs noted above. The current and long-term portions of collateral are reported as a component of energy risk management assets or liabilities and other deferred credits, respectively.

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 these contracts in which Cleco is hedging the variability of cash flows related to forecasted transactions that qualify as cash flow hedges, the changes in the fair value of such derivative instruments are reported in other comprehensive income. To qualify for hedge accounting, the relationship between the hedging instrument and the hedged item must be documented to include the risk management objective and strategy, and, at inception and on an ongoing basis, the effectiveness of the hedge in offsetting the changes in the cash flows of the item being hedged. Gains or losses accumulated in other comprehensive income are reclassified as earnings in the periods in which earnings are affected by the variability of the cash flows of the hedged item. The ineffective portions of hedges will be recognized in current period earnings unless management determines that it is probable that the costs will be recovered through the rate-making process. If management determines that it is probable that the costs will be recovered, then they will be recognized as a regulatory asset or liability and amortized to earnings over the life of the related debt. For those contracts in which Cleco is hedging the variability of cash flows related to forecasted transactions that do not qualify as cash flow hedges, the changes in the fair value of such derivative instruments will be recognized in current period earnings unless management determines that it is probable that the costs will be recovered through the rate-making process. If management determines that it is probable that the costs will be recovered, then such costs will be recognized as a regulatory asset or liability and amortized to earnings over the life of the related debt. For more information on the interest rate risk contracts, see Note 4 — “Fair Value Accounting — Interest Rate Derivatives.”

Reclassification

Reclassifications

Certain reclassifications have been made to the 2011 financial statements to conform them to the presentation used in the 2012 financial statements. These reclassifications had no effect on Cleco Corporation’s net income applicable to common stock or total common shareholders’ equity or Cleco Power’s net income or total member’s equity.

Earnings Per Share

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

Stock-Based Compensation

At September 30, 2012, 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.

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Affiliate Transactions

9 Months Ended

Sep. 30, 2012

Related Party Transactions [Abstract]

Affiliate Transactions

Note 12 — Affiliate Transactions

At September 30, 2012, Cleco Corporation had no affiliate balances that were payable to or due from its non-consolidated affiliates.

Cleco Power has affiliate balances that are payable to or due from its affiliates. At September 30, 2012, the payable to Support Group was $5.7 million, the payable to Cleco Corporation was $0.8 million, the payable to Evangeline was $3.5 million, and the payable to other affiliates was less than $0.1 million. Also, at September 30, 2012, the receivable from Support Group was $2.0 million, the receivable from Cleco Corporation was $1.3 million, and the receivable from other affiliates was less than $0.1 million.

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Disclosures about Segments

9 Months Ended

Sep. 30, 2012

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 first-tier subsidiary. Cleco’s reportable segments are Cleco Power and Midstream. The reconciling items in the following tables consist of the holding company, a shared services subsidiary, two transmission interconnection facilities, and an investment subsidiary.

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 2012 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. These intercompany transactions relate primarily to joint and common administrative support services provided by Support Group.

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED SEPTEMBER 30,
2012 (THOUSANDS)	CLECO POWER			MIDSTREAM			RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	282,894		$	—		$	—		$	—		$	282,894
Tolling operations	—			13,890			—			(13,890		)	—
Other operations	14,905			1			502			—			15,408
Electric customer credits	(930		)	—			—			—			(930		)
Affiliate revenue	343			—			12,343			(12,686		)	—
Operating revenue, net	$	297,212		$	13,891		$	12,845		$	(26,576	)	$	297,372
Depreciation	$	33,199		$	1,499		$	233		$	—		$	34,931
Interest charges	$	21,962		$	(69	)	$	(124	)	$	197		$	21,966
Interest income	$	129		$	—		$	(194	)	$	197		$	132
Federal and state income tax expense (benefit)	$	19,740		$	2,489		$	(2,050	)	$	—		$	20,179
Segment profit	$	57,783		$	3,429		$	2,606		$	—		$	63,818
Additions to long-lived assets	$	65,073		$	799		$	503		$	—		$	66,375
Equity investment in investees	$	14,532		$	—		$	9		$	—		$	14,541
Total segment assets	$	3,840,131		$	221,503		$	194,996		$	(149,737	)	$	4,106,893

2011 (THOUSANDS)	CLECO POWER		MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	324,532	$	—	$	—		$	—		$	324,532
Tolling operations	—		9,133		—			—			9,133
Other operations	15,565		1		500			(2		)	16,064
Electric customer credits	1,852		—		—			—			1,852
Affiliate revenue	347		—		13,448			(13,795		)	$	—
Operating revenue, net	$	342,296	$	9,134	$	13,948		$	(13,797	)	$	351,581
Depreciation	$	29,539	$	1,457	$	241		$	—		$	31,237
Interest charges	$	25,306	$	752	$	(308	)	$	29		$	25,779
Interest income	$	276	$	5	$	199		$	29		$	509
Equity loss from investees, before tax	$	—	$	—	$	(1	)	$	—		$	(1	)
Federal and state income tax expense (benefit)	$	31,656	$	444	$	(7,363	)	$	—		$	24,737
Segment profit	$	53,833	$	5,946	$	6,063		$	—		$	65,842
Additions to long-lived assets	$	76,213	$	4,074	$	81		$	—		$	80,368
Equity investment in investees (1)	$	14,532	$	—	$	8		$	—		$	14,540
Total segment assets  (1)	$	3,726,471	$	233,891	$	201,074		$	(111,234	)	$	4,050,202
(1) Balances as of December 31, 2011

SEGMENT INFORMATION FOR THE NINE MONTHS ENDED SEPTEMBER 30,
2012 (THOUSANDS)	CLECO POWER		MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	720,776	$	—	$	—		$	—		$	720,776
Tolling operations	—		21,434		—			(21,434		)	—
Other operations	36,967		2		1,496			(1		)	38,464
Electric customer credits	1,025		—		—			—			1,025
Affiliate revenue	1,030		—		37,540			(38,570		)	—
Operating revenue	$	759,798	$	21,436	$	39,036		$	(60,005	)	$	760,265
Depreciation	$	93,847	$	4,491	$	689		$	1		$	99,028
Interest charges	$	61,253	$	244	$	1,320		$	388		$	63,205
Interest income	$	153	$	—	$	(379	)	$	389		$	163
Equity income from investees, before tax	$	—	$	—	$	1		$	—		$	1
Federal and state income tax expense (benefit)	$	54,748	$	7,278	$	(7,916	)	$	—		$	54,110
Segment profit	$	121,873	$	11,053	$	7,610		$	—		$	140,536
Additions to long-lived assets	$	159,836	$	6,811	$	1,371		$	—		$	168,018
Equity investment in investees	$	14,532	$	—	$	9		$	—		$	14,541
Total segment assets	$	3,840,131	$	221,503	$	194,996		$	(149,737	)	$	4,106,893

2011 (THOUSANDS)	CLECO POWER			MIDSTREAM		RECONCILING ITEMS			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	823,484		$	—	$	—		$	—		$	823,484
Tolling operations	—			16,137		—			—			16,137
Other operations	40,261			8		1,511			(5		)	41,775
Electric customer credits	(3,405		)	—		—			—			(3,405		)
Affiliate revenue	1,041			45		37,544			(38,428		)	202
Operating revenue	$	861,381		$	16,190	$	39,055		$	(38,433	)	$	878,193
Depreciation	$	86,650		$	4,370	$	728		$	1		$	91,749
Interest charges	$	74,029		$	1,963	$	1,891		$	128		$	78,011
Interest income	$	557		$	6	$	103		$	128		$	794
Equity income (loss) from investees, before tax	$	—		$	62,053	$	(2	)	$	—		$	62,051
Federal and state income tax expense (benefit)	$	61,935		$	21,296	$	(9,781	)	$	1		$	73,451
Segment profit (1)	$	119,557		$	39,274	$	6,374		$	—		$	165,205
Additions to long-lived assets	$	152,082		$	5,202	$	749		$	—		$	158,033
Equity investment in investees (2)	$	14,532		$	—	$	8		$	—		$	14,540
Total segment assets (2)	$	3,726,471		$	233,891	$	201,074		$	(111,234	)	$	4,050,202
(1) Reconciliation of segment profit to consolidated profit:	Segment profit								$	165,205
(2) Balances as of December 31, 2011	Unallocated items:
	Preferred dividends requirements								26
	Preferred stock redemption costs								112
	Net income applicable to common stock								$	165,067

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Income Taxes, Income Tax Uncertainties (Details) (USD $)	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011
Uncertain Tax Positions [Abstract]
Interest payable associated with uncertain tax positions	$ 2,166,000		$ 2,166,000		$ 13,843,000
Interest charges related to uncertain tax positions	(121,000)	93,000	(8,477,000)	2,954,000
Liability for unrecognized tax benefit [Roll Forward]
Balance at beginning of period			56,235,000
Additions for tax positions of current period			640,000
Reductions for tax positions of current period			0
Additions for tax positions of proir periods			0
Reduction for tax positions of prior periods			22,418,000
Reduction for settlement with tax authority			32,062,000
Reduction for lapse of statute of limitations			0
Balance at end of period	2,395,000		2,395,000
Increase (Decrease) in Regulatory Assets and Liabilities			30,532,000	40,204,000
Cleco Power [Member]
Uncertain Tax Positions [Abstract]
Interest payable associated with uncertain tax positions	5,502,000		5,502,000		17,327,000
Interest charges related to uncertain tax positions	133,000	(420,000)	(9,504,000)	1,356,000
Regulatory Assets	6,000,000		6,000,000		9,300,000
Liability for unrecognized tax benefit [Roll Forward]
Balance at beginning of period			52,558,000
Additions for tax positions of current period			640,000
Reductions for tax positions of current period			0
Additions for tax positions of proir periods			0
Reduction for tax positions of prior periods			21,327,000
Reduction for settlement with tax authority			32,062,000
Reduction for lapse of statute of limitations			0
Balance at end of period	(191,000)		(191,000)
Increase (Decrease) in Regulatory Assets and Liabilities			$ 30,532,000	$ 40,204,000

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Pension Plan and Employee Benefits

9 Months Ended

Sep. 30, 2012

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 10 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. During the first nine months of 2012, Cleco made no discretionary or required contributions to the pension plan and does not expect to make required or discretionary contributions to the pension plan for the remainder of the year. During 2011, Cleco made $60.0 million in discretionary contributions to the pension plan, with $40.1 million designated for the 2010 plan year and the remaining $19.9 million designated for the 2011 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 are eligible to receive medical, dental, vision, and life insurance benefits (other benefits). Cleco recognizes the expected cost of these other benefits during the periods in which the benefits are earned.

The components of net periodic pension and other benefit cost for the three and nine months ended September 30, 2012 and 2011, are as follows:

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012		2011
Components of periodic benefit cost:
Service cost	$	2,078		$	2,097		$	303	$	390
Interest cost	4,563			4,407			334		443
Expected return on plan assets	(5,201		)	(6,161		)	—		—
Amortizations:
Transition obligation	—			—			5		5
Prior period service cost	(18		)	(18		)	—		(51		)
Net loss	2,087			1,389			112		246
Net periodic benefit cost	$	3,509		$	1,714		$	754	$	1,033

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012		2011
Components of periodic benefit cost:
Service cost	$	6,234		$	6,292		$	1,096	$	1,149
Interest cost	13,690			13,222			1,287		1,364
Expected return on plan assets	(15,604		)	(18,484		)	—		—
Amortizations:
Transition obligation	—			—			15		15
Prior period service cost	(53		)	(54		)	—		(154		)
Net loss	6,259			4,167			512		758
Net periodic benefit cost	$	10,526		$	5,143		$	2,910	$	3,132

Since Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred, with a like amount of assets, to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three and nine months ended September 30, 2012, was $0.5 million and $1.6 million, respectively. Amounts for the same periods in 2011 were also $0.5 million and $1.6 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 was $3.1 million at September 30, 2012. The amount at December 31, 2011, was also $3.1 million. The current portion of the other benefits liability for Cleco Power was $2.9 million at September 30, 2012. The amount at December 31, 2011, was also $2.9 million. The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2012, was $0.7 million and $2.5 million, respectively. Amounts for the same periods in 2011 were $0.9 million and $2.7 million, respectively.

In March 2010, the President signed the PPACA, a comprehensive health care law, which was upheld by the U.S. Supreme Court on June 28, 2012. While all provisions of the PPACA are not effective immediately, the provisions could increase the Registrants’ retiree medical unfunded liability and related expenses before the effective date. Management will continue to monitor this law and its possible impact on the Registrants.

SERP

Certain Cleco executive officers are covered by the SERP. The 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 and the average of the three highest 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 the SERP participants. Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ life insurance benefits, as well as future SERP payments. However, since SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco 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 the SERP were made during the three and nine months ended September 30, 2012 or 2011. Cleco Power is considered the plan sponsor, and Support Group is considered the plan administrator.

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
Components of periodic benefit cost:
Service cost	$	372	$	392	$	1,115	$	1,175
Interest cost	632		526		1,895		1,578
Amortizations:
Prior period service cost	13		13		40		40
Net loss	441		234		1,324		705
Net periodic benefit cost	$	1,458	$	1,165	$	4,374	$	3,498

The SERP liabilities are reported on the individual subsidiaries’ financial statements. At September 30, 2012 and December 31, 2011, the current portion of the SERP liability for Cleco was $2.5 million and $2.2 million, respectively. The current portion of the SERP liability for Cleco Power was $0.8 million at September 30, 2012. The amount at December 31, 2011, was also $0.8 million. The expense related to the SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income was $0.4 million and $1.1 million for the three and nine months ended September 30, 2012, respectively, compared to $0.3 million and $0.9 million for the same periods in 2011.

401(k) Plan

Most employees are eligible to participate in the 401(k) Plan. Under the 401(k) Plan, Cleco makes matching contributions and funds dividend reinvestments with cash. Cleco’s 401(k) Plan expense for the three and nine monthsended September 30, 2012 and 2011 is as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
401(k) Plan expense	$	963	$	945	$	3,303	$	2,998

Cleco Power is the plan sponsor for the 401(k) Plan. The expense of the 401(k) Plan related to Cleco’s other subsidiaries for the three and nine months ended September 30, 2012, was $0.2 million and $0.8 million, respectively. Amounts for the same periods in 2011 were $0.2 million and $0.7 million, respectively.

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Income Taxes

9 Months Ended

Sep. 30, 2012

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 and nine month periods ended September 30, 2012 and 2011.

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
	2012		2011		2012		2011
Cleco	24.0	%	27.3	%	27.8	%	30.8	%
Cleco Power	25.5	%	37.0	%	31.0	%	34.1	%

Effective Tax Rates

For the three and nine months ended September 30, 2012 and 2011, the effective income tax rate for Cleco was different than the federal statutory rate due to permanent tax deductions, flow-through of tax benefits associated with AFUDC equity, tax benefits delivered from Cleco’s investment in the NMTC Fund, other credits, favorable settlements with taxing authorities, and state tax expense.

For the three and nine months ended September 30, 2012 and 2011, the effective income tax rate for Cleco Power was different than the federal statutory rate due to permanent tax deductions, other credits, favorable settlements with taxing authorities, flow-through 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 September 30, 2012, Cleco had a deferred tax asset resulting from New Markets Tax Credit carryforwards of $75.2 million. If the New Markets Tax Credit 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 New Markets Tax Credit carryforwards will be realized; therefore, no valuation allowance has been recorded.

Net Operating Losses

Cleco Corporation filed its 2011 federal income tax return and generated a $477.7 million net operating loss carryforward. Of the $477.7 million net operating loss carryforward generated, $436.9 million is attributable to Cleco Power. The net operating loss carryforward was primarily related to a tax accounting method change for bonus depreciation associated with Madison Unit 3. On July 3, 2012, Cleco filed a Private Letter Ruling request with the IRS in order to determine the appropriateness and timing of taking this special depreciation deduction for Madison Unit 3.  The IRS is expected to take up to six months to consider the ruling request and issue a final ruling on the matter. Cleco and Cleco Power consider it more likely than not that these losses will be utilized to reduce future income taxes and both Cleco and Cleco Power expect to utilize the entire net operating loss carryforward within the next four years.

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 uncertain tax positions and related interest payable and interest expense, as reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets and Statements of Income, are shown in the following tables.

(THOUSANDS)	AT SEPT. 30, 2012		AT DEC. 31, 2011
Interest payable
Cleco	$	2,166	$	13,843
Cleco Power	$	5,502	$	17,327

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 September 30, 2012 and December 31, 2011, are $6.0 million and $9.3 million, respectively.

	FOR THE THREE MONTHS ENDED SEPT. 30,						FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012			2011
Interest charges
Cleco	$	(121	)	$	93		$	(8,477	)	$	2,954
Cleco Power	$	133		$	(420	)	$	(9,504	)	$	1,356

The interest charges reflect the amount of interest anticipated to be paid to 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 September 30, 2012 and December 31, 2011, are $3.3 million and $1.6 million, respectively.

The total liability for unrecognized tax benefits for Cleco at September 30, 2012 and December 31, 2011, is shown in the following table.

Cleco
(THOUSANDS)	LIABILITY FOR UNRECOGNIZED TAX BENEFITS
Balance at December 31, 2011	$	56,235
Additions for tax positions of current period	640
Reductions for tax positions of current period	—
Additions for tax positions of prior periods	—
Reduction for tax positions of prior periods	22,418
Reduction for settlement with tax authority	32,062
Reduction for lapse of statute of limitations	—
Balance at September 30, 2012	$	2,395

The total liability (asset) for unrecognized tax benefits for Cleco Power at September 30, 2012 and December 31, 2011, is shown in the following table.

Cleco Power
(THOUSANDS)	LIABILITY (ASSET) FOR UNRECOGNIZED TAX BENEFITS
Balance at December 31, 2011	$	52,558
Additions for tax positions of current period	640
Reductions for tax positions of current period	—
Additions for tax positions of prior periods	—
Reduction for tax positions of prior periods	21,327
Reduction for settlement with tax authority	32,062
Reduction for lapse of statute of limitations	—
Balance at September 30, 2012	$	(191	)

The federal income tax years that remain subject to examination by the IRS are 2001 through 2011. The Louisiana state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2001 through 2011. In December 2010, Cleco deposited $52.2 million with the IRS associated with the years under audit. In February 2011, Cleco deposited an additional $8.2 million with the IRS associated with the years currently under audit. Of the $60.4 million deposited, $43.5 million remains to either offset tax and interest liabilities for tax years subsequent to 2003 or to be refunded.

Cleco is currently under audit by the IRS for the years 2001 through 2009. Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of September 30, 2012, could decrease by a maximum of $0.6 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.

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Electric Customer Credits

9 Months Ended

Sep. 30, 2012

Regulated Operations [Abstract]

Electric Customer Credits

Note 9 — Electric Customer Credits

Beginning in 2010, the amount of Cleco Power’s yearly retail earnings is subject to the terms of an FRP established by the LPSC. The rates and the FRP became effective upon commencement of commercial operations at Madison Unit 3 on February 12, 2010. The 2010 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, 2011, Cleco Power filed its report for the 12 months endedJune 30, 2011, which indicated that $5.1 million was due to be returned to customers. On July 18, 2012, the LPSC approved the monitoring report for the 12 months ended June 30, 2011. Cleco Power issued refunds for this filing on customers' bills during the third quarter of 2012.

Cleco Power expects to file its monitoring report for the 12 months endedJune 30, 2012, by October 31, 2012, which will indicate $1.7 million is due to be returned to customers.

The accrual for estimated electric customer credits reflected on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2012 and December 31, 2011, was $2.5 million and $7.3 million, respectively.

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Variable Interest Entities, Ownership Interest (Details) (APH [Member])	Apr. 29, 2011
Acadia Power Partners [Member]
Significant Acquisitions and Disposals [Line Items]
Ownership interest received (in hundredths)	100.00%
Cajun [Member]
Significant Acquisitions and Disposals [Line Items]
Ownership interest exchanged (in hundredths)	50.00%

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Litigation (Details) (USD $)	1 Months Ended		12 Months Ended				3 Months Ended		12 Months Ended
	Sep. 30, 2011 Discrimiation Complaint [Member] claim plaintiff	Apr. 30, 2011 Discrimiation Complaint [Member] claim	Dec. 31, 2010 Discrimiation Complaint [Member]	Jul. 29, 2010 Discrimiation Complaint [Member] plaintiff	Jul. 31, 2012 Retaliation complaint [Member] plaintiff	Sep. 30, 2012 Other Litigation Matters [Member]	Sep. 30, 2012 Cleco Power [Member]	Mar. 09, 2010 Cleco Power [Member] City of Opelousas Litigation [Member] resident claim	Dec. 31, 2009 Minimum [Member] Discrimiation Complaint [Member]	Mar. 09, 2010 Minimum [Member] Cleco Power [Member] City of Opelousas Litigation [Member]	Jul. 29, 2010 Current Employee [Member] Discrimiation Complaint [Member] employee	Dec. 11, 2009 Current Employee [Member] Discrimiation Complaint [Member] employee	Jul. 31, 2012 Current Employee [Member] Retaliation complaint [Member] employee	Dec. 11, 2009 Former Employee [Member] Discrimiation Complaint [Member] employee	Jul. 31, 2012 Former Employee [Member] Retaliation complaint [Member] employee	Mar. 09, 2010 Customer [Member] Cleco Power [Member] City of Opelousas Litigation [Member] customer
Litigation [Abstract]
Number of plaintiffs											1	8	6	4	3	3
Minimum amount sought by plaintiffs									$ 35,000,000
Minimum amount sought by additional plaintiff			2,500,000
Total number of plaintiffs				13	9
Number of claims settled and dismissed	1	1
Number of plaintiffs remaining	11
Amount owed as a result of alleged overcharges						2,500,000				30,000,000
Number of residents in second class action lawsuit								249
Number of class action law suits								2
Fuel expenses included in audit							3,260,000,000
Cost disallowance in audit, excluding interest							400,000
Customer fuel credit refund							400,000
Environmental expenses included in audit							$ 11,300,000

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Electric Customer Credits (Details) (USD $)	12 Months Ended
	Jun. 30, 2012	Jun. 30, 2011	Sep. 30, 2012	Dec. 31, 2011	Feb. 12, 2010
Provision for rate refund			$ 2,526,000	$ 7,323,000
Cleco Power [Member]
Target return on equity allowed by FRP (in hundredths)					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 hundredths)					11.30%
Return on equity for customer credit, high range (in hundredths)					12.30%
Total customer credits	1,700,000	5,100,000
Provision for rate refund			$ 2,526,000	$ 7,323,000

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Pension Plan and Employee Benefits (Tables)

9 Months Ended

Sep. 30, 2012

Defined Benefit Plan Disclosure [Line Items]

401(k) Plan Expense

Cleco’s 401(k) Plan expense for the three and nine monthsended September 30, 2012 and 2011 is as follows:

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
401(k) Plan expense	$	963	$	945	$	3,303	$	2,998

Pension Benefits [Member]

Defined Benefit Plan Disclosure [Line Items]

Components of Net Periodic Pension and Other Benefit Costs

The components of net periodic pension and other benefit cost for the three and nine months ended September 30, 2012 and 2011, are as follows:

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012		2011
Components of periodic benefit cost:
Service cost	$	2,078		$	2,097		$	303	$	390
Interest cost	4,563			4,407			334		443
Expected return on plan assets	(5,201		)	(6,161		)	—		—
Amortizations:
Transition obligation	—			—			5		5
Prior period service cost	(18		)	(18		)	—		(51		)
Net loss	2,087			1,389			112		246
Net periodic benefit cost	$	3,509		$	1,714		$	754	$	1,033

	PENSION BENEFITS						OTHER BENEFITS
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012			2011			2012		2011
Components of periodic benefit cost:
Service cost	$	6,234		$	6,292		$	1,096	$	1,149
Interest cost	13,690			13,222			1,287		1,364
Expected return on plan assets	(15,604		)	(18,484		)	—		—
Amortizations:
Transition obligation	—			—			15		15
Prior period service cost	(53		)	(54		)	—		(154		)
Net loss	6,259			4,167			512		758
Net periodic benefit cost	$	10,526		$	5,143		$	2,910	$	3,132

SERP Benefits [Member]

Defined Benefit Plan Disclosure [Line Items]

Components of Net Periodic Pension and Other Benefit Costs

Cleco Power is considered the plan sponsor, and Support Group is considered the plan administrator.

	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2012		2011		2012		2011
Components of periodic benefit cost:
Service cost	$	372	$	392	$	1,115	$	1,175
Interest cost	632		526		1,895		1,578
Amortizations:
Prior period service cost	13		13		40		40
Net loss	441		234		1,324		705
Net periodic benefit cost	$	1,458	$	1,165	$	4,374	$	3,498

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Fair Value Accounting, Fair Values of Derivative Instruments (Details) (Derivatives Not Designated As Hedging Instruments [Member], USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Fair values of derivative instruments [Abstract]
Total	$ 0	$ (5,336)
Energy Risk Management Liability, Net [Member] | Fuel Cost Hedges [Member]
Fair values of derivative instruments [Abstract]
Current	$ 0	$ (5,336)

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Storm Restoration

9 Months Ended

Sep. 30, 2012

Storm Restoration [Abstract]

Storm Restoration

Note 14 — Storm Restoration

On August 28, 2012, Hurricane Isaac made landfall in south Louisiana as a Category 1 hurricane, causing power outages to approximately 95,000, or 34%, of Cleco Power’s electric customers and affecting Cleco Power’s entire service territory. By September 2, 2012, power was restored to 100% of customers who could receive power.

The current estimate of the cost of restoration for Hurricane Isaac is approximately $21.4 million. The damage to equipment from the storm required replacement, as well as repair of existing assets. Therefore, the balance sheets of Cleco and Cleco Power reflect the capitalization of approximately 61.8% of the restoration costs recorded at September 30, 2012, or approximately $13.2 million. The remaining cost was offset against Cleco Power’s existing storm damage reserve.

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Fair Value Accounting (Policies)

9 Months Ended

Sep. 30, 2012

Fair Value Disclosures [Abstract]

Concentration Risk, Credit Risk, Policy

In May 2012, Cleco and Cleco Power revised their guidelines for short-term investments in order to mitigate credit risk. Qualifying investments include:

• U.S. treasury securities,

• U.S. federal agency and U.S. government-sponsored entity debt,

• Tax-exempt short-term securities of a state, territory, or a possession of the U.S.,

• Certificates of deposit, banker's acceptances and time deposits,

• Corporate notes and bonds, fixed or floating rate, and covered bonds,

• Commercial paper,

• Asset backed securities with a minimum long-term rating of AA by Standard & Poor's and Aaa by Moody's,

• U.S. government mortgage securities with a short average life with a minimum long-term rating of AA by Standard & Poor's and Aaa by Moody's,

• Repurchase agreements with the primary government securities dealers or financial institutions in which Cleco deposits and/or concentrates cash, and

• Money market funds which must have at least $15.0 billion in assets under management; must have been in existence for not less than two years; must have a minimum rating of AAA by Standard & Poor's and Aaa by Moody's and must be compliant with the SEC rule 2a-7 which restricts the quality, maturity, and diversity of investments by money market funds.

The minimum acceptable short-term credit rating must be A-1 by Standard & Poor's and P-1 by Moody's. The maximum maturity of any instrument must be 36 months, and the maximum portfolio duration must be 12 months.

Diversification of holdings must be stressed recognizing the total amount of the portfolio. Investments in securities of any one issuer will be limited to 5% at the time of purchase except for U.S. Treasury and Agency Securities and money market funds. No more than 50% of the portfolio at the time of purchase will be invested in any single Federal Agency/Government Sponsored Enterprise.

Fair Value Transfer, Policy

Cleco has a policy which states that transfers between Levels 1, 2, and 3 are recognized at the end of a reporting period.

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Fair Value Accounting, Derivatives (Details) (Cleco Power [Member], Forward Starting Interest Rate Swap [Member], USD $) In Millions, unless otherwise specified	0 Months Ended	3 Months Ended	9 Months Ended
	Nov. 14, 2011	Sep. 30, 2012	Sep. 30, 2012	Dec. 31, 2011
Cleco Power [Member] | Forward Starting Interest Rate Swap [Member]
Interest rate cash flow hedge [Abstract]
Notional amount	$ 50.0
Derivative Instruments, Gain Recognized in Other Comprehensive Income (Loss), Effective Portion		0.8
Rate basis	spot 30-year all-in swap
Fixed iterest rate	3.05%
Amount of original notional amount issuance delayed	50.0
Unrealized mark-to-market loss in other comprehensive income			(0.7)
Interest rate risk management asset		$ 4.1	$ 4.1	$ 3.3

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Summary of Significant Accounting Policies Summary of Significant Accounting Policies, Reclassifications (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		9 Months Ended
	Sep. 30, 2012	Sep. 30, 2011	Sep. 30, 2012	Sep. 30, 2011	Dec. 31, 2011	Dec. 31, 2010
Increase (Decrease) in Accounts Receivable			$ (13,247)	$ (21,691)
Depreciation	34,931	31,237	99,028	91,749
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net			(17,388)	2,181
Net Cash Provided by (Used in) Operating Activities, Continuing Operations			224,604	263,590
Payments to Acquire Property, Plant, and Equipment			(177,146)	(146,617)
Net Cash Provided by (Used in) Investing Activities			(149,218)	(55,045)
Cash and Cash Equivalents, Period Increase (Decrease)			(25,212)	(32,896)
Cash and Cash Equivalents, at Carrying Value	68,364	158,232	68,364	158,232	93,576	191,128
Cash Flows Related To Contributions Received In Aid Of Construction [Member]
Increase (Decrease) in Accounts Receivable				(21,691)
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net				2,181
Net Cash Provided by (Used in) Operating Activities, Continuing Operations				263,590
Payments to Acquire Property, Plant, and Equipment				(146,617)
Net Cash Provided by (Used in) Investing Activities				(55,045)
Cash and Cash Equivalents, Period Increase (Decrease)				(32,896)
Cash and Cash Equivalents, at Carrying Value		158,232		158,232		191,128
Cash Flows Related To Contributions Received In Aid Of Construction [Member] | Scenario, Previously Reported [Member]
Increase (Decrease) in Accounts Receivable				(18,274)
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net				(2,184)
Net Cash Provided by (Used in) Operating Activities, Continuing Operations				262,642
Payments to Acquire Property, Plant, and Equipment				(145,669)
Net Cash Provided by (Used in) Investing Activities				(54,097)
Cash and Cash Equivalents, Period Increase (Decrease)				(32,896)
Cash and Cash Equivalents, at Carrying Value		158,232		158,232		191,128
Cleco Power [Member]
Increase (Decrease) in Accounts Receivable			(13,807)	(23,859)
Depreciation	33,199	29,539	93,847	86,650
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net			(20,057)	(1,996)
Net Cash Provided by (Used in) Operating Activities, Continuing Operations			205,527	185,636
Payments to Acquire Property, Plant, and Equipment			(173,268)	(131,962)
Net Cash Provided by (Used in) Investing Activities			(138,329)	(113,804)
Cash and Cash Equivalents, Period Increase (Decrease)			(16,880)	(41,897)
Cash and Cash Equivalents, at Carrying Value	50,578	143,015	50,578	143,015	67,458	184,912
Cleco Power [Member] | Cash Flows Related To Contributions Received In Aid Of Construction [Member]
Increase (Decrease) in Accounts Receivable				(23,859)
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net				(1,996)
Net Cash Provided by (Used in) Operating Activities, Continuing Operations				185,636
Payments to Acquire Property, Plant, and Equipment				(131,962)
Net Cash Provided by (Used in) Investing Activities				(113,804)
Cash and Cash Equivalents, Period Increase (Decrease)				(41,897)
Cash and Cash Equivalents, at Carrying Value		143,015		143,015		184,912
Cleco Power [Member] | Cash Flows Related To Contributions Received In Aid Of Construction [Member] | Scenario, Previously Reported [Member]
Increase (Decrease) in Accounts Receivable				(20,442)
Increase (Decrease) in Other Noncurrent Assets and Liabilities, Net				(6,361)
Net Cash Provided by (Used in) Operating Activities, Continuing Operations				184,688
Payments to Acquire Property, Plant, and Equipment				(131,014)
Net Cash Provided by (Used in) Investing Activities				(112,856)
Cash and Cash Equivalents, Period Increase (Decrease)				(41,897)
Cash and Cash Equivalents, at Carrying Value		143,015		143,015		184,912
Reclassification Of Plant Acquisition Adjustment Amortization [Member]
Depreciation		$ 700		$ 2,100

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Consolidated Balance Sheets (USD $) In Thousands, unless otherwise specified	Sep. 30, 2012	Dec. 31, 2011
Current assets
Cash and cash equivalents	$ 68,364	$ 93,576
Restricted cash and cash equivalents	3,406	8,761
Customer accounts receivable	47,635	37,813
Other accounts receivable	36,334	42,051
Taxes receivable	8,353	44,584
Unbilled revenue	31,505	30,129
Fuel inventory, at average cost	53,290	41,845
Material and supplies inventory, at average cost	58,212	53,714
Accumulated deferred federal and state income taxes, net	75,693	29,249
Accumulated deferred fuel	1,715	2,136
Cash surrender value of company-/trust-owned life insurance policies	56,647	51,073
Prepayments	5,095	5,384
Regulatory assets- other	12,810	13,028
Other current assets	398	3,442
Total current assets	459,457	456,785
Property, plant, and equipment
Property, plant, and equipment	4,082,636	4,023,655
Accumulated depreciation	(1,291,862)	(1,230,783)
Net property, plant, and equipment	2,790,774	2,792,872
Construction work in progress	183,529	101,027
Total property, plant, and equipment, net	2,974,303	2,893,899
Equity investment in investees	14,541	14,540
Prepayments	4,139	4,770
Restricted cash and cash equivalents, less current portion	13,320	27,067
Restricted investments	4,470	0
Regulatory assets and liabilities - deferred taxes, net	219,433	214,421
Regulatory assets - other	258,344	269,444
Net investment in direct financing lease	13,546	13,633
Intangible asset	123,608	133,595
Other deferred charges	21,732	22,048
Total assets	4,106,893	4,050,202
Liabilities
Long-term debt, net	1,237,184	1,337,056
Current liabilities
Short-term debt	0	0
Long-term debt due within one year	90,937	24,258
Accounts payable	104,435	129,308
Customer deposits	45,197	43,091
Provision for rate refund	2,526	7,323
Interest accrued	27,249	22,642
Energy risk managment liability, net	0	5,336
Interest rate risk management liability	4,063	3,330
Regulatory liabilities - other	8,251	33,019
Deferred compensation	9,604	8,302
Uncertain tax positions	31	27,239
Other current liabilities	17,559	17,154
Total current liabilities	309,852	321,002
Deferred credits
Accumulated deferred federal and state income taxes, net	760,602	649,926
Accumulated deferred investment tax credits	6,547	7,432
Postretirement benefit obligations	138,414	133,274
Regulatory liabilities - other	0	7,303
Restricted storm reserve	16,019	24,880
Uncertain tax positions	2,184	23,494
Tax credit fund investment, net	85,307	61,507
Contingent sale obligations	10,350	29,357
Other deferred credits	38,580	35,114
Total deferred credits	1,058,003	972,287
Total liabilities	2,605,039	2,630,345
Commitments and contingencies (Note 11)
Shareholders' equity
Common stock	60,957	60,702
Premium on common stock	415,289	409,904
Retained earnings	1,072,468	990,605
Treasury stock, at cost	(21,085)	(13,215)
Accumulated other comprehensive loss	(25,775)	(28,139)
Total shareholders' equity	1,501,854	1,419,857
Total liabilities and shareholders' equity	4,106,893	4,050,202
Cleco Power [Member]
Current assets
Cash and cash equivalents	50,578	67,458
Restricted cash and cash equivalents	3,406	8,761
Customer accounts receivable	47,635	37,813
Accounts receivable - affiliate	3,373	2,405
Other accounts receivable	35,969	35,618
Taxes receivable	0	3,197
Unbilled revenue	31,505	30,129
Fuel inventory, at average cost	53,290	41,845
Material and supplies inventory, at average cost	55,465	51,132
Accumulated deferred federal and state income taxes, net	74,116	19,829
Accumulated deferred fuel	1,715	2,136
Cash surrender value of company-/trust-owned life insurance policies	20,742	20,433
Prepayments	4,172	4,155
Regulatory assets- other	12,810	13,028
Other current assets	393	375
Total current assets	395,169	338,314
Property, plant, and equipment
Property, plant, and equipment	3,815,608	3,759,541
Accumulated depreciation	(1,209,401)	(1,153,004)
Net property, plant, and equipment	2,606,207	2,606,537
Construction work in progress	180,777	97,595
Total property, plant, and equipment, net	2,786,984	2,704,132
Equity investment in investees	14,532	14,532
Prepayments	4,139	4,770
Restricted cash and cash equivalents, less current portion	13,223	26,970
Restricted investments	4,470	0
Regulatory assets and liabilities - deferred taxes, net	219,433	214,421
Regulatory assets - other	258,344	269,444
Intangible asset	123,608	133,595
Other deferred charges	20,229	20,293
Total assets	3,840,131	3,726,471
Liabilities
Member's equity	1,296,433	1,230,862
Long-term debt, net	1,237,184	1,327,056
Total capitalization	2,533,617	2,557,918
Current liabilities
Short-term debt	0	0
Long-term debt due within one year	90,937	24,258
Accounts payable	96,370	115,091
Accounts payable - affiliate	10,069	9,311
Customer deposits	45,197	43,091
Provision for rate refund	2,526	7,323
Taxes payable	20,019	0
Interest accrued	28,806	22,540
Energy risk managment liability, net	0	5,336
Interest rate risk management liability	4,063	3,330
Regulatory liabilities - other	8,251	33,019
Uncertain tax positions	0	27,465
Other current liabilities	13,580	11,193
Total current liabilities	319,818	301,957
Deferred credits
Accumulated deferred federal and state income taxes, net	828,195	675,835
Accumulated deferred investment tax credits	6,547	7,432
Postretirement benefit obligations	98,450	94,147
Regulatory liabilities - other	0	7,303
Restricted storm reserve	16,019	24,880
Uncertain tax positions	222	19,906
Other deferred credits	37,263	37,093
Total deferred credits	986,696	866,596
Commitments and contingencies (Note 11)
Shareholders' equity
Total liabilities and shareholders' equity	$ 3,840,131	$ 3,726,471

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Regulatory Assets and Liabilities

9 Months Ended

Sep. 30, 2012

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 September 30, 2012 and December 31, 2011:

(THOUSANDS)	AT SEPT. 30, 2012			AT DEC. 31, 2011
Regulatory assets – deferred taxes, net	$	219,433		$	214,421
Mining costs	$	17,206		$	19,117
Interest costs	6,394			6,667
Asset removal costs	851			829
Postretirement plan costs	126,349			132,556
Tree trimming costs	6,335			8,371
Training costs	7,369			7,486
Storm surcredits, net	5,958			9,254
Construction carrying costs	6,262			10,883
Lignite mining agreement contingency	3,781			3,781
Power purchase agreement capacity costs	5,921			—
AFUDC equity gross-up	73,906			74,346
Rate case costs	716			1,117
Acadia Unit 1 acquisition costs	2,892			2,971
IRP/RFP costs	156			508
AMI pilot costs	54			153
Financing costs	6,851			4,433
Biomass costs	153			—
Total regulatory assets – other	$	271,154		$	282,472
Construction carrying costs	(8,251		)	(40,322		)
Fuel and purchased power	1,715			2,136
Total regulatory assets, net	$	484,051		$	458,707

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 allows Cleco Power to defer and recover a portion of capacity costs associated with the power purchase agreement. The deferred costs will be collected over the term of the contract.

Financing Costs

In 2011, Cleco Power entered into and settled two treasury rate locks. Of the $26.8 million in settlements, $6.9 million was recorded as a regulatory asset relating to ineffectiveness of the hedge relationship. As a result of management’s assessment that it is probable that the ineffectiveness will be recovered through the rate-making process, Cleco Power will amortize the regulatory asset over the 30-year term of the related debt issuance.

Biomass Test Burn Costs

In November 2011, the LPSC approved Cleco Power’s request to establish a regulatory asset for the non-fuel, non-capital portion of costs incurred to conduct a test burn of biomass fuel at Madison Unit 3. These costs will be amortized over a five-year period.

Construction Carrying Costs

In February 2006, the LPSC approved Cleco Power’s plans to build Madison Unit 3. Terms of the approval included authorization for Cleco Power to collect from customers an amount equal to 75% of the LPSC-jurisdictional portion of the carrying costs of capital during the construction phase of the unit. Cleco Power’s retail rate plan, which was approved in October 2009, established that Cleco Power return carrying costs to customers and record a regulatory asset for all carrying costs incurred by Cleco Power above the actual amount collected from customers. On February 12, 2010, Madison Unit 3 commenced commercial operations and Cleco Power began returning the construction carrying costs to customers. These costs are being amortized over a four-year period. As of September 30, 2012, Cleco Power had returned $158.2 million to customers. At September 30, 2012, $8.3 million was due to be returned to customers within one year.

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Income Taxes, Valuation Allowance (Details) (New Markets Tax Credit [Member], USD $) In Millions, unless otherwise specified	9 Months Ended
	Sep. 30, 2012
New Markets Tax Credit [Member]
Tax Credit Carryforward [Line Items]
Tax credit carryforwards	$ 75.2
Expiration date	Jan. 01, 2029

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Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees, Other Commitments (Details) (USD $)	3 Months Ended	9 Months Ended
	Sep. 30, 2012	Sep. 30, 2012	Aug. 31, 2008
New Markets Tax Credits [Abstract]
Membership interest in U.S Bank New Markets Tax Credit Fund (in hundredths)			99.90%
Equity contributions to be made to the Fund		$ 285,500,000
Net tax benefits to be received from the Fund		303,800,000
Difference between equity contributions and total benefits received will be recognized over the life of the Fund as net tax benefits		18,300,000
Future equity contributions [Abstract]
Three months ending December 31, 2012	12,786,000	12,786,000
Year ending Dec. 31, 2013	50,822,000	50,822,000
Year ending Dec. 31, 2014	39,059,000	39,059,000
Year ending Dec. 31, 2015	12,975,000	12,975,000
Year ending Dec. 31, 2016	11,890,000	11,890,000
Year ending Dec. 31, 2017	3,292,000	3,292,000
Total future equity contributions	130,824,000	130,824,000
Equity contributions in next 12 months	51,600,000	51,600,000
Equity contributions with an imputed interest rate [Abstract]
Equity contributions - imputed interst rate	6.00%	6.00%
Principal payment schedule above:	130,824,000	130,824,000
Less: unamortized discount	12,291,000	12,291,000
Total	118,533,000	118,533,000
Tax benefits in excess of capital contributions		104,700,000
Tax benefits not utilized	$ 86,500,000	$ 86,500,000
Remaining Period of Recognition of Gross Investment Amortization Expense	5
Period of Recognition of Gross Investment Amortization Expense	10

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Pension Plan and Employee Benefits (Policies)

9 Months Ended

Sep. 30, 2012

Compensation and Retirement Disclosure [Abstract]

Pension and Other Postretirement Plans, Policy [Policy Text Block]

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 10 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.

401(k) Plan

Most employees are eligible to participate in the 401(k) Plan. Under the 401(k) Plan, Cleco makes matching contributions and funds dividend reinvestments with cash.

SERP

Certain Cleco executive officers are covered by the SERP. The 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 and the average of the three highest 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’s retirees and their dependents are 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.

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

9 Months Ended

Sep. 30, 2012

Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees [Abstract]

Off-Balance Sheet Commitments

Cleco’s off-balance sheet commitments as of September 30, 2012, 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 SEPT. 30, 2012
(THOUSANDS)	FACE AMOUNT		REDUCTIONS		NET AMOUNT
Cleco Corporation
Guarantee issued to Entergy Mississippi on behalf of Attala	$	500	$	—	$	500
Cleco Power
Obligations under standby letter of credit issued to the Louisiana Department of Labor	3,725		—		3,725
Total	$	4,225	$	—	$	4,225

Expected Termination Dates of Off-Balance Sheet Commitments and On-Balance Sheet Guarantees

The following table summarizes the expected termination dates of the off-balance sheet commitments and on-balance sheet guarantees discussed above.

							AT SEPT. 30, 2012
			AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
(THOUSANDS)	NET AMOUNT COMMITTED		LESS THAN ONE YEAR		1-3 YEARS		3-5 YEARS		MORE THAN 5 YEARS
Off-balance sheet commitments	$	4,225	$	3,725	$	—	$	—	$	500
On-balance sheet guarantees	14,356		—		10,350		—		4,006
Total	$	18,581	$	3,725	$	10,350	$	—	$	4,506

Future Equity Contributions

The following table reflects remaining future equity contributions.

(THOUSANDS)	CONTRIBUTION
Three months ending Dec. 31, 2012	$	12,786
Years ending Dec. 31,
2013	50,822
2014	39,059
2015	12,975
2016	11,890
2017	3,292
Total	$	130,824

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:	$	130,824
Less:  unamortized discount	12,291
Total	$	118,533

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Acadia Unit 2 Transaction

9 Months Ended

Sep. 30, 2012

Acquisition and Disposal Transactions [Abstract]

Acadia Transactions

Note 13 — Acadia Unit 2 Transaction

On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 and Acadia Power Station’s remaining common facilities to Entergy Louisiana. The significant terms of the transaction were:

• Entergy Louisiana acquired Acadia Unit 2 for $298.8 million,

• In exchange for $10.9 million, APH indemnified the third-party owners of Cajun and their affiliates against 50% of Acadia’s liabilities and other obligations related to the Acadia Unit 2 transaction,

• APH recognized a gain of $62.0 million, which included $26.2 million of equity income that represents the 2007 investment impairment charge of $45.9 million, partially offset by $19.7 million of capitalized interest during the construction of Acadia,

• APH received 100% ownership in Acadia in exchange for its 50% interest in Cajun, and Acadia became a consolidated subsidiary of APH, and

• Cleco Power operates Acadia Unit 2 on behalf of Entergy Louisiana.

Following the transaction, ongoing operations at Acadia are minimal, relating only to the previously established accounts receivable, accounts payable, and servicing of indemnities. Therefore, Acadia does not meet the definition of a business.