Cleco Power 10Q 2013 Q3 Quarterly report

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, 2013


¨	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 25, 2013

Cleco Corporation	Common Stock, $1.00 Par Value	60,452,158

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		2013 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.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

GLOSSARY OF TERMS

References in this filing to “Cleco”, including all items in Parts I and II, 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 which is the greater of the prime rate, the federal funds effective rate plus 0.50%, or the LIBOR plus 1.0%
Acadia	Acadia Power Partners, LLC, a wholly owned subsidiary of Acadia Power Holdings LLC, a wholly owned subsidiary of Midstream
Acadia Unit 1	Cleco Power’s 580-MW unit, a combined-cycle, natural gas-fired power plant located at the Acadia Power Station in Eunice, Louisiana
Acadia Unit 2	Entergy Louisiana’s 580-MW unit, a combined-cycle, natural gas-fired power plant located at the Acadia Power Station in Eunice, Louisiana
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
Attala	Attala Transmission LLC, a wholly owned subsidiary of Cleco Corporation
CERCLA	The Comprehensive Environmental Response, Compensation, and Liability Act of 1980
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 St. Landry, Louisiana
DHLC	Dolet Hills Lignite Company, LLC, a wholly owned subsidiary of SWEPCO
Diversified Lands	Diversified Lands LLC, a wholly owned subsidiary of Cleco Corporation
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
Dolet Hills	A 650-MW lignite/natural gas generating unit at Cleco Power’s plant site in Mansfield, Louisiana. Cleco Power has a 50% ownership interest in the capacity of Dolet Hills.
Entergy	Entergy Corporation
Entergy Gulf States	Entergy Gulf States Louisiana, L.L.C.
Entergy Louisiana	Entergy Louisiana, LLC
Entergy Mississippi	Entergy Mississippi, Inc.
EPA	United States Environmental Protection Agency
ERO	Electric Reliability Organization
ESPP	Cleco Corporation Employee Stock Purchase Plan
Evangeline	Cleco Evangeline LLC, a wholly owned subsidiary of Midstream
FAC	Fuel Adjustment Clause
FASB	Financial Accounting Standards Board
FERC	Federal Energy Regulatory Commission
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)
Interconnection Agreement	One of two Interconnection 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
kWh	Kilowatt-hour(s) as applicable
LIBOR	London Inter-Bank Offer Rate
Lignite Mining Agreement	Dolet Hills Mine Lignite Mining Agreement, dated as of May 31, 2001
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
MATS	Mercury and Air Toxics Standards
Midstream	Cleco Midstream Resources LLC, a wholly owned subsidiary of Cleco Corporation
MISO	Midcontinent Independent System Operator, Inc.
Moody’s	Moody’s Investors Service
MW	Megawatt(s) as applicable
NERC	North American Electric Reliability Corporation
NMTC	New Markets Tax Credit
NMTC Fund	USB NMTC Fund 2008-1 LLC was formed to invest in projects qualifying for New Markets Tax Credits and Solar Projects
Not Meaningful	A percentage comparison of these items is not statistically meaningful because the percentage difference is greater than 1,000%
OATT	Open Access Transmission Tariff



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



ABBREVIATION OR ACRONYM	DEFINITION
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, Inc., as agent for Entergy Louisiana and Entergy Gulf States
PRP	Potentially responsible party
Registrant(s)	Cleco Corporation and Cleco Power
RFP	Request for Proposal
Rodemacher Unit 2	A 523-MW coal/natural gas generating unit at Cleco Power’s plant site in Boyce, Louisiana. Cleco Power has a 30% ownership interest in the capacity of Rodemacher Unit 2.
RTO	Regional Transmission Organization
Sale Agreement	Purchase and Sale Agreement, dated as of January 28, 2004, between Perryville and Entergy Louisiana
S&P	Standard & Poor’s Ratings Services, a credit rating agency
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.
VIE	Variable Interest Entity



CLECO CORPORATION
CLECO POWER		2013 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 existing customers and service to new customers; future environmental regulations and remediation liabilities; electric customer credits; and the anticipated outcome of various regulatory and legal proceedings. Although the Registrants believe that the expectations reflected in such forward-looking statements are reasonable, such forward-looking statements are based on numerous assumptions (some of which may prove to be incorrect) and are subject to risks and uncertainties that could cause the actual results to differ materially from the Registrants’ expectations. In addition to any assumptions and other factors referred to specifically in connection with these forward-looking statements, the following list identifies some of the factors that could cause the Registrants’ actual results to differ materially from those contemplated in any of the Registrants’ forward-looking statements:

•

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 and 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 maintain its right to sell wholesale generation at market-based rates within its control area,


•	Cleco Power’s dependence on energy from sources other than its facilities and future sources of such additional energy,


•	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, participation in an RTO and Cleco Power’s ability to recover related transmission upgrade costs, the

compliance with the ERO reliability standards for bulk power systems by Cleco Power and Evangeline, and the change in market conditions resulting from MISO that could affect Cleco’s ability to create, maintain, and renew energy sales contracts with new and existing customers,


•	reliance on third parties for determination of Cleco Power’s commitments and obligations to markets for generation resources and reliance on third party transmission services,


•	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, including the potential impact from the automatic reductions in U.S. federal government spending that went into effect in the first quarter of 2013, known as sequestration, the partial U.S. federal government shutdown in October 2013, and the ongoing debates related to the U.S. federal government budget and debt ceiling,


•	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 increased conservation efforts of customers,


•	reliability of Cleco Power’s and Midstream’s 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 AMI project and the transfer of Coughlin to Cleco Power,



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q


•	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 and energy efficiency that could limit or terminate the operation of certain generating units, increase costs, or reduce customer demand for electricity,


•	the ability of Cleco Power to recover from its customers the costs of compliance with environmental laws and regulations, including capital expenditures associated with MATS, and


•	the 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, 2012. 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.



CLECO CORPORATION
CLECO POWER		2013 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, 2012. 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.”



CLECO CORPORATION
CLECO POWER		2013 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)	2013			2012
Operating revenue
Electric operations	$	314,766		$	282,894
Other operations	14,843			15,408
Gross operating revenue	329,609			298,302
Electric customer credits	(846		)	(930		)
Operating revenue, net	328,763			297,372
Operating expenses
Fuel used for electric generation	101,752			79,701
Power purchased for utility customers	5,999			19,364
Other operations	30,057			30,517
Maintenance	20,427			20,059
Depreciation	41,756			34,931
Taxes other than income taxes	12,007			9,455
Gain on sale of assets	(29		)	(2		)
Total operating expenses	211,969			194,025
Operating income	116,794			103,347
Interest income	332			132
Allowance for other funds used during construction	1,303			1,882
Other income	2,837			1,834
Other expense	(1,456		)	(1,232		)
Interest charges
Interest charges, including amortization of debt expense, premium, and discount, net	19,436			22,610
Allowance for borrowed funds used during construction	(422		)	(644		)
Total interest charges	19,014			21,966
Income before income taxes	100,796			83,997
Federal and state income tax expense	34,389			20,179
Net income applicable to common stock	$	66,407		$	63,818

Average number of basic common shares outstanding	60,450,384			60,346,476
Average number of diluted common shares outstanding	60,748,647			60,599,203
Basic earnings per share
Net income applicable to common stock	$	1.10		$	1.06
Diluted earnings per share
Net income applicable to common stock	$	1.09		$	1.05
Cash dividends paid per share of common stock	$	0.3625		$	0.3375
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO CORPORATION

Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013		2012
Net income	$	66,407	$	63,818
Other comprehensive income, net of tax:
Amortization of postretirement benefits (net of tax expense of $311 in 2013 and $239 in 2012)	497		332
Net gain on cash flow hedges (net of tax expense of $33 in 2013 and $302 in 2012)	53		483
Total other comprehensive income, net of tax	550		815
Comprehensive income, net of tax	$	66,957	$	64,633
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 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)	2013			2012
Operating revenue
Electric operations	$	796,957		$	720,776
Other operations	37,917			38,464
Gross operating revenue	834,874			759,240
Electric customer credits	(1,270		)	1,025
Operating revenue, net	833,604			760,265
Operating expenses
Fuel used for electric generation	259,728			207,764
Power purchased for utility customers	24,795			44,069
Other operations	88,420			86,901
Maintenance	64,372			61,478
Depreciation	110,529			99,028
Taxes other than income taxes	34,926			29,198
Loss (gain) on sale of assets	817			(57		)
Total operating expenses	583,587			528,381
Operating income	250,017			231,884
Interest income	789			163
Allowance for other funds used during construction	2,880			4,298
Equity income from investees, before tax	—			1
Other income	12,282			24,223
Other expense	(2,146		)	(2,718		)
Interest charges
Interest charges, including amortization of debt expense, premium, and discount, net	62,284			64,671
Allowance for borrowed funds used during construction	(926		)	(1,466		)
Total interest charges	61,358			63,205
Income before income taxes	202,464			194,646
Federal and state income tax expense	66,892			54,110
Net income applicable to common stock	$	135,572		$	140,536

Average number of basic common shares outstanding	60,428,944			60,375,538
Average number of diluted common shares outstanding	60,694,632			60,626,471
Basic earnings per share
Net income applicable to common stock	$	2.25		$	2.33
Diluted earnings per share
Net income applicable to common stock	$	2.23		$	2.32
Cash dividends paid per share of common stock	$	1.0625		$	0.9625
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO CORPORATION

Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013		2012
Net income	$	135,572	$	140,536
Other comprehensive income, net of tax:
Amortization of postretirement benefits (net of tax expense of $1,013 in 2013 and $670 in 2012)	1,619		1,221
Net gain on cash flow hedges (net of tax expense of $892 in 2013 and $715 in 2012)	1,426		1,143
Total other comprehensive income, net of tax	3,045		2,364
Comprehensive income, net of tax	$	138,617	$	142,900
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO CORPORATION

Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2013			AT DEC. 31, 2012
Assets
Current assets
Cash and cash equivalents	$	46,800		$	31,020
Restricted cash and cash equivalents	3,359			8,781
Customer accounts receivable (less allowance for doubtful accounts of $823 in 2013 and $1,105 in 2012)	56,434			39,293
Other accounts receivable	42,671			37,741
Taxes receivable, net	—			34,612
Unbilled revenue	33,629			28,662
Fuel inventory, at average cost	48,909			46,867
Material and supplies inventory, at average cost	62,450			58,232
Accumulated deferred federal and state income taxes, net	1,132			79,353
Accumulated deferred fuel	6,851			7,833
Cash surrender value of company-/trust-owned life insurance policies	62,682			57,346
Prepayments	6,326			5,951
Regulatory assets - other	6,109			11,095
Other current assets	206			552
Total current assets	377,558			447,338
Property, plant, and equipment
Property, plant, and equipment	4,272,907			4,140,194
Accumulated depreciation	(1,371,857		)	(1,311,273		)
Net property, plant, and equipment	2,901,050			2,828,921
Construction work in progress	151,254			180,540
Total property, plant, and equipment, net	3,052,304			3,009,461
Equity investment in investees	14,541			14,540
Prepayments	4,119			4,261
Restricted cash and cash equivalents	5,112			5,440
Restricted investments	12,275			10,852
Regulatory assets - deferred taxes, net	217,550			210,445
Regulatory assets - other	298,520			289,570
Net investment in direct financing lease	13,528			13,542
Intangible asset	109,552			120,545
Other deferred charges	22,458			21,355
Total assets	$	4,127,517		$	4,147,349
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

(Continued on next page)



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO CORPORATION

Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2013			AT DEC. 31, 2012
Liabilities and shareholders’ equity
Liabilities
Current liabilities
Long-term debt due within one year	$	17,147		$	91,140
Accounts payable	86,768			102,695
Customer deposits	48,287			45,553
Provision for rate refund	2,967			4,165
Taxes payable	35,671			—
Interest accrued	24,750			12,957
Interest rate risk management liability	—			2,627
Regulatory liabilities - other	—			8,255
Deferred compensation	10,424			9,626
Uncertain tax positions	4,610			686
Other current liabilities	14,171			16,926
Total current liabilities	244,795			294,630
Deferred credits
Accumulated deferred federal and state income taxes, net	755,868			762,992
Accumulated deferred investment tax credits	5,421			6,252
Postretirement benefit obligations	156,950			186,746
Restricted storm reserve	17,309			16,285
Uncertain tax positions	—			2,184
Tax credit fund investment, net	48,806			78,840
Contingent sale obligations	900			8,150
Other deferred credits	28,564			34,799
Total deferred credits	1,013,818			1,096,248
Long-term debt, net	1,290,990			1,257,258
Total liabilities	2,549,603			2,648,136
Commitments and Contingencies (Note 11)
Shareholders’ equity
Common shareholders’ equity
Common stock, $1 par value, authorized 100,000,000 shares, issued 61,047,006 and 60,961,570 shares and outstanding 60,452,158 and 60,355,545 shares at September 30, 2013 and December 31, 2012, respectively	61,047			60,962
Premium on common stock	420,913			416,619
Retained earnings	1,145,962			1,075,074
Treasury stock, at cost, 594,848 and 606,025 shares at September 30, 2013 and December 31, 2012, respectively	(20,683		)	(21,072		)
Accumulated other comprehensive loss	(29,325		)	(32,370		)
Total shareholders’ equity	1,577,914			1,499,213
Total liabilities and shareholders’ equity	$	4,127,517		$	4,147,349
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO CORPORATION

Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013			2012
Operating activities
Net income	$	135,572		$	140,536
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	120,792			122,676
Unearned compensation expense	4,707			4,986
Allowance for other funds used during construction	(2,880		)	(4,298		)
Net deferred income taxes	60,172			8,040
Deferred fuel costs	2,906			(4,218		)
Cash surrender value of company-/trust-owned life insurance	(1,631		)	(2,841		)
Changes in assets and liabilities:
Accounts receivable	(30,167		)	(13,247		)
Unbilled revenue	(4,967		)	(1,376		)
Fuel, materials and supplies inventory	(5,595		)	(15,943		)
Accounts payable	(15,691		)	(25,422		)
Customer deposits	9,777			8,772
Postretirement benefit obligations	(26,968		)	5,459
Regulatory assets and liabilities, net	(28,727		)	(30,532		)
Other deferred accounts	(7,480		)	(17,388		)
Taxes accrued	70,188			36,021
Interest accrued	11,793			7,616
Other operating	(2,136		)	5,763
Net cash provided by operating activities	289,665			224,604
Investing activities
Additions to property, plant, and equipment	(131,521		)	(177,146		)
Allowance for other funds used during construction	2,880			4,298
Property, plant, and equipment grants	729			15,075
Insurance reimbursement for property loss	—			5,454
Premiums paid on company-/trust-owned life insurance	(3,705		)	(2,733		)
Return of equity investment in tax credit fund	473			37,132
Contributions to tax credit fund	(38,940		)	(46,859		)
Transfer of cash from restricted accounts	5,750			19,102
Purchase of restricted investments	(6,422		)	(4,340		)
Maturity of restricted investments	5,003			—
Other investing	942			799
Net cash used in investing activities	(164,811		)	(149,218		)
Financing activities
Draws on credit facility	198,000			—
Payments on credit facility	(223,000		)	(10,000		)
Issuance of long-term debt	160,000			50,000
Retirement of long-term debt	(113,969		)	(74,368		)
Repurchase of long-term debt	(60,000		)	—
Repurchase of common stock	—			(8,007		)
Settlement of interest rate swap	(3,269		)	—
Dividends paid on common stock	(64,448		)	(58,459		)
Other financing	(2,388		)	236
Net cash used in financing activities	(109,074		)	(100,598		)
Net increase (decrease) in cash and cash equivalents	15,780			(25,212		)
Cash and cash equivalents at beginning of period	31,020			93,576
Cash and cash equivalents at end of period	$	46,800		$	68,364
Supplementary cash flow information
Interest paid (net of amount capitalized)	$	45,464		$	48,212
Income taxes refunded, net	$	(47,318	)	$	(131	)
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	12,869		$	16,657
Non-cash additions to property, plant, and equipment, net	$	1,280		$	18,395
Issuance of common stock – ESPP	$	240		$	257
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO CORPORATION

Condensed Consolidated Statements of Changes in Common Shareholders’ Equity (Unaudited)
	COMMON STOCK			TREASURY STOCK					PREMIUM ON COMMON STOCK		RETAINED EARNINGS			ACCUMULATED OTHER COMPREHENSIVE LOSS			TOTAL SHAREHOLDERS’ EQUITY
(THOUSANDS, EXCEPT SHARE AMOUNTS)	SHARES	AMOUNT		SHARES		COST			PREMIUM ON COMMON STOCK		RETAINED EARNINGS			ACCUMULATED OTHER COMPREHENSIVE LOSS			TOTAL SHAREHOLDERS’ EQUITY
Balances, Dec. 31, 2011	60,702,342	$	60,702	(410,403	)	$	(13,215	)	$	409,904	$	990,605		$	(28,139	)	$	1,419,857
Common stock issued for compensatory plans	254,540	255		4,002		136			5,385		—			—			5,776
Repurchase of common stock	—	—		(200,000	)	(8,006		)	—		—			—			(8,006		)
Dividends on common stock, $0.9625 per share	—	—		—		—			—		(58,673		)	—			(58,673		)
Net income	—	—		—		—			—		140,536			—			140,536
Other comprehensive income, net of tax	—	—		—		—			—		—			2,364			2,364
Balances, Sept. 30, 2012	60,956,882	$	60,957	(606,401	)	$	(21,085	)	$	415,289	$	1,072,468		$	(25,775	)	$	1,501,854

Balances, Dec. 31, 2012	60,961,570	$	60,962	(606,025	)	$	(21,072	)	$	416,619	$	1,075,074		$	(32,370	)	$	1,499,213
Common stock issued for compensatory plans	85,436	85		11,177		389			4,294		—			—			4,768
Dividends on common stock, $1.0625 per share	—	—		—		—			—		(64,684		)	—			(64,684		)
Net income	—	—		—		—			—		135,572			—			135,572
Other comprehensive income, net of tax	—	—		—		—			—		—			3,045			3,045
Balances, Sept. 30, 2013	61,047,006	$	61,047	(594,848	)	$	(20,683	)	$	420,913	$	1,145,962		$	(29,325	)	$	1,577,914
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 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, 2012. 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.”



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO POWER

Condensed Consolidated Statements of Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013			2012
Operating revenue
Electric operations	$	314,766		$	282,894
Other operations	14,301			14,905
Affiliate revenue	335			343
Gross operating revenue	329,402			298,142
Electric customer credits	(846		)	(930		)
Operating revenue, net	328,556			297,212
Operating expenses
Fuel used for electric generation	101,752			79,701
Power purchased for utility customers	18,339			33,254
Other operations	28,471			29,063
Maintenance	17,478			16,095
Depreciation	39,962			33,199
Taxes other than income taxes	10,891			8,390
Total operating expenses	216,893			199,702
Operating income	111,663			97,510
Interest income	331			129
Allowance for other funds used during construction	1,303			1,882
Other income	2,838			1,188
Other expense	(2,239		)	(1,224		)
Interest charges
Interest charges, including amortization of debt expense, premium, and discount, net	19,078			22,606
Allowance for borrowed funds used during construction	(422		)	(644		)
Total interest charges	18,656			21,962
Income before income taxes	95,240			77,523
Federal and state income tax expense	33,355			19,740
Net income	$	61,885		$	57,783
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO POWER

Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013		2012
Net income	$	61,885	$	57,783
Other comprehensive income, net of tax:
Amortization of postretirement benefits (net of tax expense of $130 in 2013 and $103 in 2012)	207		124
Net gain on cash flow hedges (net of tax expense of $33 in 2013 and $302 in 2012)	53		483
Total other comprehensive income, net of tax	260		607
Comprehensive income, net of tax	$	62,145	$	58,390
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO POWER

Condensed Consolidated Statements of Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013			2012
Operating revenue
Electric operations	$	796,957		$	720,776
Other operations	36,366			36,967
Affiliate revenue	1,005			1,030
Gross operating revenue	834,328			758,773
Electric customer credits	(1,270		)	1,025
Operating revenue, net	833,058			759,798
Operating expenses
Fuel used for electric generation	259,728			207,459
Power purchased for utility customers	51,278			65,493
Other operations	83,385			82,647
Maintenance	55,857			51,739
Depreciation	105,251			93,847
Taxes other than income taxes	31,554			26,004
Gain on sale of assets	—			(1		)
Total operating expenses	587,053			527,188
Operating income	246,005			232,610
Interest income	784			153
Allowance for other funds used during construction	2,880			4,298
Other income	4,606			3,511
Other expense	(3,693		)	(2,698		)
Interest charges
Interest charges, including amortization of debt expense, premium, and discount, net	61,808			62,719
Allowance for borrowed funds used during construction	(926		)	(1,466		)
Total interest charges	60,882			61,253
Income before income taxes	189,700			176,621
Federal and state income tax expense	65,558			54,748
Net income	$	124,142		$	121,873
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO POWER

Condensed Consolidated Statements of Comprehensive Income (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013		2012
Net income	$	124,142	$	121,873
Other comprehensive income, net of tax:
Amortization of postretirement benefits (net of tax expense of $455 in 2013 and $267 in 2012)	727		555
Net gain on cash flow hedges (net of tax expense of $892 in 2013 and $715 in 2012)	1,426		1,143
Total other comprehensive income, net of tax	2,153		1,698
Comprehensive income, net of tax	$	126,295	$	123,571
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO POWER

Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2013			AT DEC. 31, 2012
Assets
Utility plant and equipment
Property, plant, and equipment	$	4,001,194		$	3,871,940
Accumulated depreciation	(1,283,205		)	(1,227,078		)
Net property, plant, and equipment	2,717,989			2,644,862
Construction work in progress	147,369			176,584
Total utility plant, net	2,865,358			2,821,446
Current assets
Cash and cash equivalents	42,560			23,368
Restricted cash and cash equivalents	3,359			8,781
Customer accounts receivable (less allowance for doubtful accounts of $823 in 2013 and $1,105 in 2012)	56,434			39,293
Accounts receivable - affiliate	1,260			2,991
Other accounts receivable	42,453			37,562
Unbilled revenue	33,629			28,662
Fuel inventory, at average cost	48,909			46,867
Material and supplies inventory, at average cost	59,597			55,472
Accumulated deferred federal and state income taxes, net	8,306			87,286
Accumulated deferred fuel	6,851			7,833
Cash surrender value of company-owned life insurance policies	19,234			20,842
Prepayments	4,528			4,415
Regulatory assets - other	6,109			11,095
Other current assets	—			371
Total current assets	333,229			374,838
Equity investment in investee	14,532			14,532
Prepayments	4,119			4,261
Restricted cash and cash equivalents	5,015			5,343
Restricted investments	12,275			10,852
Regulatory assets - deferred taxes, net	217,550			210,445
Regulatory assets - other	298,520			289,570
Intangible asset	109,552			120,545
Other deferred charges	21,241			19,897
Total assets	$	3,881,391		$	3,871,729
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.

(Continued on next page)



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO POWER

Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)	AT SEPT. 30, 2013		AT DEC. 31, 2012
Liabilities and member’s equity
Member’s equity	$	1,371,214	$	1,319,919
Long-term debt, net	1,290,990		1,232,258
Total capitalization	2,662,204		2,552,177
Current liabilities
Long-term debt due within one year	17,147		91,140
Accounts payable	77,529		89,782
Accounts payable - affiliate	10,240		10,097
Customer deposits	48,287		45,553
Provision for rate refund	2,967		4,165
Taxes payable	21,371		1,328
Interest accrued	26,074		13,893
Interest rate risk management liability	—		2,627
Regulatory liabilities - other	—		8,255
Other current liabilities	10,744		11,746
Total current liabilities	214,359		278,586
Commitments and Contingencies (Note 11)
Deferred credits
Accumulated deferred federal and state income taxes, net	848,020		845,769
Accumulated deferred investment tax credits	5,421		6,252
Postretirement benefit obligations	106,636		137,637
Restricted storm reserve	17,309		16,285
Uncertain tax positions	—		222
Other deferred credits	27,442		34,801
Total deferred credits	1,004,828		1,040,966
Total liabilities and member’s equity	$	3,881,391	$	3,871,729
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO POWER

Condensed Consolidated Statements of Cash Flows (Unaudited)
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013			2012
Operating activities
Net income	$	124,142		$	121,873
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation and amortization	114,078			102,724
Allowance for other funds used during construction	(2,880		)	(4,298		)
Net deferred income taxes	70,864			43,259
Deferred fuel costs	2,906			(4,218		)
Changes in assets and liabilities:
Accounts receivable	(30,125		)	(13,807		)
Unbilled revenue	(4,967		)	(1,376		)
Fuel, materials and supplies inventory	(5,500		)	(15,778		)
Accounts payable	(12,296		)	(20,474		)
Customer deposits	9,777			8,772
Postretirement benefit obligations	(29,784		)	4,323
Regulatory assets and liabilities, net	(28,727		)	(30,532		)
Other deferred accounts	(10,143		)	(20,057		)
Taxes accrued	20,043			23,194
Interest accrued	12,182			9,482
Other operating	2,427			2,440
Net cash provided by operating activities	231,997			205,527
Investing activities
Additions to property, plant, and equipment	(126,977		)	(173,268		)
Allowance for other funds used during construction	2,880			4,298
Property, plant, and equipment grants	729			15,075
Transfer of cash from restricted accounts	5,750			19,102
Purchase of restricted investments	(6,422		)	(4,340		)
Maturity of restricted investments	5,003			—
Other investing	857			804
Net cash used in investing activities	(118,180		)	(138,329		)
Financing activities
Draws on credit facility	160,000			—
Payments on credit facility	(160,000		)	—
Issuance of long-term debt	160,000			50,000
Retirement of long-term debt	(113,969		)	(74,368		)
Repurchase of long-term debt	(60,000		)	—
Settlement of interest rate swap	(3,269		)	—
Distribution to parent	(75,000		)	(58,000		)
Other financing	(2,387		)	(1,710		)
Net cash used in financing activities	(94,625		)	(84,078		)
Net increase (decrease) in cash and cash equivalents	19,192			(16,880		)
Cash and cash equivalents at beginning of period	23,368			67,458
Cash and cash equivalents at end of period	$	42,560		$	50,578
Supplementary cash flow information
Interest paid (net of amount capitalized)	$	45,248		$	48,140
Income taxes refunded, net	$	(456	)	$	(246	)
Supplementary non-cash investing and financing activities
Accrued additions to property, plant, and equipment	$	12,591		$	16,141
Non-cash additions to property, plant, and equipment, net	$	1,280		$	18,395
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



CLECO POWER

Condensed Consolidated Statements of Changes in Member’s Equity (Unaudited)
(THOUSANDS)	RETAINED EARNINGS			ACCUMULATED OTHER COMPREHENSIVE LOSS			TOTAL MEMBER’S EQUITY
Balances, Dec. 31, 2011	$	1,251,492		$	(20,630	)	$	1,230,862
Other comprehensive income, net of tax	—			1,698			1,698
Distribution to parent	(58,000		)	—			(58,000		)
Net income	121,873			—			121,873
Balances, Sept. 30, 2012	$	1,315,365		$	(18,932	)	$	1,296,433

Balances, Dec. 31, 2012	$	1,340,340		$	(20,421	)	$	1,319,919
Other comprehensive income, net of tax	—			2,153			2,153
Distribution to parent	(75,000		)	—			(75,000		)
Net income	124,142			—			124,142
Balances, Sept. 30, 2013	$	1,389,482		$	(18,268	)	$	1,371,214
The accompanying notes are an integral part of the Condensed Consolidated Financial Statements.



CLECO CORPORATION
CLECO POWER		2013 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	Storm Restoration	Cleco Corporation and Cleco Power
Note 14	Accumulated Other Comprehensive Loss	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 in accordance with GAAP for interim financial information and with the instructions to Form 10-Q and Regulation S-X. Accordingly, these Condensed Consolidated Financial Statements do not include all of the information and notes required by GAAP for annual financial statements. The year-end Condensed Consolidated Balance Sheet data was derived from audited financial statements. Because the interim Condensed Consolidated Financial Statements and the accompanying notes do not include all of the information and notes required by GAAP for annual financial statements, the Condensed Consolidated Financial Statements and other information included in this quarterly report should be read in conjunction with the consolidated financial statements and accompanying notes in the Registrants’ Combined Annual Report on Form 10-K for the year ended December 31, 2012.

These Condensed Consolidated Financial Statements, in the opinion of management, reflect all normal recurring adjustments that are necessary to fairly present the financial position and results of operations of Cleco. Amounts reported in Cleco’s interim financial statements are not necessarily indicative of amounts expected for the annual periods due to the effects of seasonal temperature variations on energy consumption, regulatory rulings, the timing of maintenance on electric generating units, changes in mark-to-market valuations, changing commodity prices, and other factors.

In preparing financial statements that conform to GAAP, management must make estimates and assumptions that affect the reported amounts of assets and liabilities, the

reported amounts of revenues and expenses, and the disclosure of contingent assets and liabilities at the date of the financial statements. Actual results could differ from those estimates. For more information on recent authoritative guidance and its effect on financial results, see Note 2 — “Recent Authoritative Guidance.”

Property, Plant, and Equipment

Property, plant, and equipment consists primarily of regulated utility generation and energy transmission assets. Regulated assets, utilized primarily for retail operations and electric transmission and distribution, are stated at the cost of construction, which includes certain materials, labor, payroll taxes and benefits, administrative and general costs, and the estimated cost of funds used during construction. Jointly owned assets are reflected in property, plant, and equipment at Cleco Power’s share of the cost to construct or purchase the assets. Cleco’s property, plant, and equipment consisted of:



(THOUSANDS)	AT SEPT. 30, 2013			AT DEC. 31, 2012
Regulated utility plants	$	4,001,194		$	3,871,940
Other	271,713			268,254
Total property, plant, and equipment	4,272,907			4,140,194
Accumulated depreciation	(1,371,857		)	(1,311,273		)
Net property, plant, and equipment	$	2,901,050		$	2,828,921

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, 2013		AT DEC. 31, 2012
Diversified Lands’ mitigation escrow	$	97	$	97
Cleco Katrina/Rita’s storm recovery bonds	3,359		8,781
Cleco Power’s future storm restoration costs	4,944		5,343
Cleco Power’s building renovation escrow	71		—
Total restricted cash and cash equivalents	$	8,471	$	14,221



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

Cleco Katrina/Rita has the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash is collected, it is restricted for payment of administration fees, interest, and principal on storm recovery bonds. During the nine months ended September 30, 2013, Cleco Katrina/Rita collected $14.9 million net of administration fees. In March and September 2013, Cleco Katrina/Rita used $7.1 million and $6.8 million, respectively, for scheduled storm recovery bond principal payments and $3.3 million and $3.1 million, respectively, for related interest.

In connection with Cleco Power’s building modernization project, Cleco Power was required to establish an escrow account with a qualified financial institution and deposit all retainage monies as they accrue under the construction contract. Upon completion of the construction work, the funds including any interest held in the escrow account will be released from escrow and paid to the construction contractor.

Fair Value Measurements and Disclosures

Various accounting pronouncements require certain assets and liabilities to be measured at their fair values. Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance. Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP. For more information about fair value levels, see Note 4 — “Fair Value Accounting.”

Risk Management

Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power 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 in accordance with regulatory policy. When these positions close, actual gains or losses will be included in the FAC and reflected on

customers’ bills as a component of the fuel cost adjustment. There were no open positions at September 30, 2013 or December 31, 2012.

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 ratemaking process. If management determines that it is probable that the costs will be recovered from customers, 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 from customers through the ratemaking process. If management determines that it is probable that the costs will be recovered from customers, then they 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.”

Earnings per Average Common Share

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



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



						FOR THE THREE MONTHS ENDED SEPT. 30,
				2013					2012
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Basic net income applicable to common stock	$	66,407	60,450,384	$	1.10	$	63,818	60,346,476	$	1.06
Effect of dilutive securities
Add: stock option grants			—					1,536
Add: restricted stock (LTICP)			298,263					251,191
Diluted net income applicable to common stock	$	66,407	60,748,647	$	1.09	$	63,818	60,599,203	$	1.05



						FOR THE NINE MONTHS ENDED SEPT. 30,
				2013					2012
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)	INCOME		SHARES	PER SHARE AMOUNT		INCOME		SHARES	PER SHARE AMOUNT
Basic net income applicable to common stock	$	135,572	60,428,944	$	2.25	$	140,536	60,375,538	$	2.33
Effect of dilutive securities
Add: stock option grants			—					4,518
Add: restricted stock (LTICP)			265,688					246,415
Diluted net income applicable to common stock	$	135,572	60,694,632	$	2.23	$	140,536	60,626,471	$	2.32

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. All stock options were exercised during 2012 and no additional options were granted during the nine months ended September 30, 2013.

Stock-Based Compensation

At September 30, 2013, 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 nine months ended September 30, 2013, Cleco granted 139,048 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)	2013		2012		2013		2012		2013		2012		2013		2012
Equity classification
Non-vested stock	$	1,585	$	1,139	$	492	$	301	$	4,487	$	3,271	$	1,204	$	792
Stock options	—		2		—		—		—		11		—		—
Total equity classification	$	1,585	$	1,141	$	492	$	301	$	4,487	$	3,282	$	1,204	$	792
Liability classification
Common stock equivalent units	$	—	$	847	$	—	$	338	$	1	$	1,552	$	1	$	631
Total pre-tax compensation expense	$	1,585	$	1,988	$	492	$	639	$	4,488	$	4,834	$	1,205	$	1,423
Tax benefit	$	610	$	765	$	189	$	246	$	1,727	$	1,860	$	463	$	548

Note 2 — Recent Authoritative Guidance

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

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 did not have an impact on the financial condition, results of operations, or cash flows of the Registrants.

In January 2013, FASB clarified the scope of revised disclosure requirements related to balance sheet offsetting that was issued in December 2011. The amendment clarifies that the scope applies to derivatives accounted for in accordance with the authoritative guidance for derivatives and hedging. The adoption of this revision is required for interim and annual periods beginning on or after January 1, 2013. The adoption of this revision did not have an impact on the financial condition, results of operations, or cash flows of the Registrants because it relates to disclosures, and no additional disclosures were required.

In February 2013, FASB revised the disclosure requirements related to items reclassified out of accumulated other comprehensive income. This guidance is intended to improve the transparency of changes in OCI. This revision is effective for fiscal years, and interim periods within those years, beginning after December 15, 2012. Cleco adopted the



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

revisions to this amendment during the first quarter of 2013. The adoption of this revision did not have an impact on the financial condition, results of operations, or cash flows of the Registrants because it relates to disclosures. For more information on items reclassified out of accumulated other comprehensive income, see Note 14 — “Accumulated Other Comprehensive Loss.”

In February 2013, FASB issued guidance for the recognition, measurement, and disclosure of obligations resulting from joint and several liability arrangements for which the total amount of the obligation is fixed at the reporting date. The adoption of this guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance is not expected to have a material impact on the financial condition, results of operations, or cash flows of the Registrants.

In April 2013, FASB issued guidance on applying the liquidation basis of accounting and the related disclosure requirements. Under this accounting standards update, an entity must use the liquidation basis of accounting to present its financial statements when it determines that liquidation is imminent, unless the liquidation is the same as that under the plan specified in an entity's governing documents created at its inception. The adoption of this standard is effective for entities that determine liquidation is imminent during annual reporting periods beginning after December 15, 2013, and interim reporting periods therein. The adoption of this guidance is not expected to have an effect on the financial condition, results of operations, or cash flows of the Registrants.

In July 2013, FASB amended the guidance for derivatives and hedging to provide for the inclusion of the Fed Funds Effective Swap Rate as a U.S. benchmark interest rate for hedge accounting purposes. The adoption of this guidance is effective for qualifying new or redesignated hedging relationships entered into on or after July 17, 2013. The adoption of this guidance did not have an effect on the financial condition, results of operations, or cash flows of the Registrants.

In July 2013, FASB amended the income tax guidance to provide for the presentation of an unrecognized tax benefit when a net operating loss carryforward, a similar tax loss, or a tax credit carryforward exists. The adoption of this guidance is effective for fiscal years, and interim periods within those years, beginning after December 15, 2013. The adoption of this guidance is not expected to have an effect on the financial condition, results of operations, or cash flows 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, 2013 and December 31, 2012:



(THOUSANDS)	AT SEPT. 30, 2013		AT DEC. 31, 2012
Regulatory assets – deferred taxes, net	$	217,550	$	210,445
Mining costs	$	14,657	$	16,569
Interest costs	6,033		6,304
Asset removal costs	919		867
Postretirement plan costs	146,597		156,458
Tree trimming costs	4,945		5,656
Training costs	7,214		7,330
Surcredits, net	16,738		6,211
Construction carrying costs	—		4,697
Lignite mining agreement contingency	3,781		3,781
Power purchase agreement capacity costs	13,316		6,217
AMI deferred revenue requirement	3,960		1,483
AFUDC equity gross-up	73,518		74,158
Rate case costs	179		581
Acadia Unit 1 acquisition costs	2,786		2,865
IRP/RFP costs	—		39
AMI pilot costs	—		22
Financing costs	9,864		7,282
Biomass costs	122		145
Total regulatory assets – other	$	304,629	$	300,665
Construction carrying costs	—		(8,255		)
Fuel and purchased power	6,851		7,833
Total regulatory assets, net	$	529,030	$	510,688

Surcredits, Net

Cleco Power has recorded surcredits as the result of a settlement with the LPSC that addressed, among other things, the recovery of the storm damages related to hurricanes and uncertain tax positions. In the settlement, Cleco Power was required to implement surcredits to provide ratepayers with the economic benefit of the carrying charges of certain accumulated deferred income tax liabilities at a rate of return which was set by the LPSC. The settlement, through a true-up mechanism, allows the surcredits to be adjusted to reflect the actual tax deductions allowed by the IRS.

Cleco Power also was allowed to record a corresponding regulatory asset in an amount representing the flow back of the carrying charges to ratepayers. This amount is being amortized over various terms of the established surcredits.

As a result of a settlement with the LPSC, Cleco Power is required to implement a surcredit when funds are withdrawn from the restricted storm reserve. In September 2012, Cleco Power withdrew $10.0 million from the restricted storm reserve to pay for storm damages, resulting in the establishment of a new surcredit. This surcredit will be utilized to partially replenish the storm reserve.

In the third quarter of 2013, Cleco Power recorded a true-up to the surcredits to reflect the actual tax deductions allowed by the IRS for storm damages and uncertain tax positions. As a result of the true-up, Cleco Power has recorded a regulatory asset that represents the amounts that will be collected from ratepayers in future periods.

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 a portion of the carrying costs of capital during the construction phase of the unit. Cleco Power’s retail rate plan 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



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

customers. These costs were amortized over a four-year period. As of June 30, 2013, Cleco Power had returned $166.0 million to customers, which represents all amounts due to be refunded to customers.

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 are being collected over the term of the contract.

AMI Deferred Revenue Requirement

In February 2011, the LPSC approved Cleco Power’s stipulated settlement in Docket No. U-31393 allowing Cleco Power to defer, as a regulatory asset, the estimated revenue requirements for the AMI project. The amount of the regulatory asset, including carrying charges, is capped by the LPSC at $20.0 million. The regulatory asset will amortize over the economic life of the project, currently estimated at 15 years.

Financing Costs

In 2011, Cleco Power entered into and settled two treasury rate locks. Also in 2011, Cleco Power entered into a forward starting swap contract. These derivatives were entered into in order to mitigate the interest rate exposure on coupon payments related to forecasted debt issuances. In May 2013, the forward starting interest rate swap was settled at a loss of $3.3 million. Cleco Power deferred $2.9 million of the losses as a regulatory asset. As a result of management’s

assessment that it is probable that these costs will be recovered through the ratemaking process, Cleco Power is amortizing the regulatory asset over the terms of the related debt issuances.

Fuel and Purchased Power Costs

The cost of fuel used for electric generation and the cost of power purchased for utility customers are recovered through the LPSC-established FAC, which enables Cleco Power to pass on to its customers substantially all such charges. For the three months ended September 30, 2013, approximately 88% of Cleco Power’s total fuel cost was regulated by the LPSC, while the remainder was regulated by FERC.

The $1.0 million decrease in the under-recovered costs was primarily due to higher fuel cost recovery revenue partially offset by an increase in per-unit costs of fuel and purchased power and higher volumes of fuel used for electric generation.

Note 4 — Fair Value Accounting

The amounts reflected in Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2013 and December 31, 2012, 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, 2013				AT DEC. 31, 2012
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market:
Cash and cash equivalents	$	46,800	$	46,800	$	31,020	$	31,020
Restricted cash and cash equivalents	$	8,471	$	8,471	$	14,221	$	14,221
Long-term debt, excluding debt issuance costs	$	1,306,230	$	1,419,560	$	1,345,198	$	1,579,674



Cleco Power
	AT SEPT. 30, 2013				AT DEC. 31, 2012
(THOUSANDS)	CARRYING VALUE		ESTIMATED FAIR VALUE		CARRYING VALUE		ESTIMATED FAIR VALUE
Financial instruments not marked-to-market:
Cash and cash equivalents	$	42,560	$	42,560	$	23,368	$	23,368
Restricted cash and cash equivalents	$	8,374	$	8,374	$	14,124	$	14,124
Long-term debt, excluding debt issuance costs	$	1,306,230	$	1,419,560	$	1,320,198	$	1,554,674

At September 30, 2013, 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 $45.6 million ($37.3 million of cash equivalents and $8.3 million of restricted cash equivalents) in short-term investments in institutional money market funds. Cleco Power had $41.8 million ($33.5 million of cash equivalents and $8.3 million of restricted cash equivalents) in short-term investments in institutional money market funds. If the money market funds fail to perform under the terms of the investments, Cleco and Cleco Power will be exposed to a loss of the invested amounts. Collateral on these

types of investments is not required by either Cleco or Cleco Power.

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



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

authoritative guidance for fair value measurements and disclosures.



Cleco
	CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2013		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2012		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	$	47,901	$	—	$	47,901	$	—	$	39,489	$	—	$	39,489	$	—
Municipal bonds	9,631		—		9,631		—		10,203		—		10,203		—
Corporate bonds	513		—		513		—		—		—		—		—
Total assets	$	58,045	$	—	$	58,045	$	—	$	49,692	$	—	$	49,692	$	—
Liability Description
Interest rate derivatives	$	—	$	—	$	—	$	—	$	2,627	$	—	$	2,627	$	—
Long-term debt	1,419,560		—		1,419,560		—		1,579,674		—		1,579,674		—
Total liabilities	$	1,419,560	$	—	$	1,419,560	$	—	$	1,582,301	$	—	$	1,582,301	$	—



Cleco Power
	CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
(THOUSANDS)	AT SEPT. 30, 2013		QUOTED PRICES IN ACTIVE MARKETS FOR IDENTICAL ASSETS (LEVEL 1)		SIGNIFICANT OTHER OBSERVABLE INPUTS (LEVEL 2)		SIGNIFICANT UNOBSERVABLE INPUTS (LEVEL 3)		AT DEC. 31, 2012		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	$	44,005	$	—	$	44,005	$	—	$	33,292	$	—	$	33,292	$	—
Municipal bonds	9,631		—		9,631		—		10,203		—		10,203		—
Corporate bonds	513		—		513		—		—		—		—		—
Total assets	$	54,149	$	—	$	54,149	$	—	$	43,495	$	—	$	43,495	$	—
Liability Description
Interest rate derivatives	$	—	$	—	$	—	$	—	$	2,627	$	—	$	2,627	$	—
Long-term debt	1,419,560		—		1,419,560		—		1,554,674		—		1,554,674		—
Total liabilities	$	1,419,560	$	—	$	1,419,560	$	—	$	1,557,301	$	—	$	1,557,301	$	—

Cleco utilizes different valuation techniques for fair value calculations. In order to measure the fair value for Level 1 assets and liabilities, Cleco obtains the closing price from published indices in active markets for the various instruments and multiplies this price by the appropriate number of instruments held. Cleco had no Level 1 assets or liabilities at September 30, 2013 or December 31, 2012. 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 for each 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, 2013 or December 31, 2012.

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.

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, non-current restricted cash and cash equivalents, and restricted investments of $37.3 million, $3.4 million,

$5.1 million, and $2.1 million, respectively, at September 30, 2013. 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, non-current restricted cash and cash equivalents, and restricted investments and were $33.5 million, $3.4 million, $5.0 million, and $2.1 million, respectively, at September 30, 2013. 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 municipal and corporate bonds were reported on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets in restricted investments in the amount of $9.6 million and $0.5 million at September 30, 2013, respectively. The Level 2 municipal bonds and the Level 2 corporate bonds consisted of a single class. In order to maximize income, meet the requirements established by the LPSC, and maintain safety and liquidity for the restricted reserve fund, restricted cash and cash equivalents were invested in short-term, fixed-income debt instruments. The risks associated with this class are counterparty risk of the fund manager and risk of price volatility associated with the municipal bonds and corporate bonds. Quarterly, Cleco receives reports from the custody agent for



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

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 contained only one instrument. The risks were changes in the three-month LIBOR rate and counterparty risk. This instrument was 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 and variable rate debt with various tenors. The fair value of this class fluctuates as the market interest rates for fixed and variable rate debt with similar tenors and credit ratings change. The fair value of the debt could also change from period to period due to changes in the credit rating of the Cleco entity that issued the debt.

During the nine months ended September 30, 2013, and the year ended December 31, 2012, Cleco did not experience any transfers between levels.

Restricted Investments

In September 2007, the LPSC authorized the funding and securitization of a $50.0 million reserve for Cleco Power’s future storm costs. On July 1, 2012, Cleco Power transferred $13.0 million of the related restricted cash and cash equivalents to an outside investment manager. Investments made by the investment manager are restricted to the criteria established by management in Cleco Power’s guidelines for short-term investments. At September 30, 2013, the investments included cash and cash equivalents and debt securities.

The cash and cash equivalents are reflected in Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2013, as restricted cash and cash equivalents and approximate fair value because of their short-term nature.

The debt securities are recorded at fair value on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2013, as restricted investments. The investments in debt securities include municipal bonds, corporate bonds, and commercial paper with original maturity

dates of more than three months and are classified as available-for-sale securities and reported at fair value. Because Cleco Power’s investment strategy for these investments is 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 determines that an other-than-temporary decline in value exists on its debt securities, the investments would be written down to fair value with a new 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 debt securities as of September 30, 2013, were caused by interest rate movements. Cleco Power does not intend to sell the debt securities 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 other-than-temporary impairments on its debt securities at September 30, 2013.

The following table provides a reconciliation of Cleco Power’s available-for-sale debt securities from amortized cost to fair value at September 30, 2013 and December 31, 2012:



	AT SEPT. 30, 2013									AT DEC. 31, 2012
(THOUSANDS)	AMORTIZED COST		TOTAL UNREALIZED GAINS ⁽¹⁾			TOTAL UNREALIZED LOSSES ⁽¹⁾		FAIR VALUE		AMORTIZED COST		TOTAL UNREALIZED GAINS ⁽¹⁾		TOTAL UNREALIZED LOSSES ⁽¹⁾		FAIR VALUE
Municipal bonds	$	9,641	$	5		$	15	$	9,631	$	10,228	$	3	$	28	$	10,203
Corporate bonds	515		—			2		513		—		—		—		—
Commercial paper	2,131		—		—	—		2,131		649		—		—		649
Total available-for-sale debt securities	$	12,287	$	5		$	17	$	12,275	$	10,877	$	3	$	28	$	10,852
⁽¹⁾ Unrealized gains and losses are recorded to the restricted storm reserve.

Cleco Power recognized less than $0.1 million unrealized mark-to-market gains in the restricted storm reserve for both the three and nine months ended September 30, 2013. Cleco Power recognized less than $0.1 million 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 debt securities that were in an unrealized loss position at September 30, 2013, 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	$	7	$	2,698	$	8	$	2,518
Corporate bonds	2		513		—		—
Total	$	9	$	3,211	$	8	$	2,518



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

At September 30, 2013, the fair value of Cleco Power’s available-for-sale debt securities by contractual maturity was:



(THOUSANDS)	AT SEPT. 30, 2013
One year or less	$	5,740
Over one year through five years	6,535
Total fair value	$	12,275

There were no realized gains or losses on Cleco Power’s available-for-sale debt securities during the three and nine months ended September 30, 2013 and 2012. Realized gains and losses will be determined on a specific identification basis.

Derivatives and Hedging

The authoritative guidance on derivatives and hedging requires entities to provide transparent disclosures about a company’s derivative activities and how the related hedged items affect a company’s financial position, financial performance, and cash flows. Cleco is required to provide qualitative and quantitative disclosures about derivative fair value, gains and losses, and credit-risk-related contingent features in derivative agreements.

For the three and nine months ended September 30, 2013, there was no effect on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for derivatives not designated as hedging instruments. For the three and nine months ended September 30, 2012, Cleco and Cleco Power recognized losses in Fuel used for electric generation on the Condensed Consolidated Statements of Income of $0.6 million and $8.2 million, respectively, for derivatives not designated as hedging instruments. In accordance with the authoritative guidance for regulated operations, there were no unrealized gains or losses and no deferred losses associated with fuel cost hedges reported in Accumulated deferred fuel on Cleco and Cleco Power’s Condensed Consolidated Balance Sheets as of September 30, 2013 and December 31, 2012. As gains and losses are realized in future periods, they will be reported as Fuel used for electric generation on Cleco and Cleco Power’s Condensed Consolidated Statements of Income.

At December 31, 2012, Cleco and Cleco Power’s Condensed Consolidated Balance Sheets had no derivative instruments not designated as hedging instruments.

At September 30, 2013 and December 31, 2012, Cleco Power had no open positions hedged for natural gas.

In November 2011, Cleco Power entered into a pay fixed/receive variable forward starting interest rate swap contract in order to mitigate the interest rate exposure on coupon payments related to the remaining $50.0 million fixed-rate forecasted debt issuance. The forward starting interest rate swap had a spot 30-year all-in swap rate of 3.05%, notional amount of $50.0 million, with the pricing date of May 14, 2013, or the issuance of the notes, whichever was earlier. The forward starting interest rate swap met the criteria of a cash flow hedge under the authoritative guidance as it related to derivatives and hedging and was carried on the balance sheet at its fair value. Because of the inputs and common techniques used to calculate fair value, the swap valuation was considered Level 2.

2008 Series B GO Zone bonds, Cleco Power settled the forward starting interest rate swap at a loss of $3.3 million. Of this amount, Cleco Power deferred $2.9 million as a regulatory asset and recognized $0.4 million in other comprehensive income. In May 2013, Cleco Power began amortizing these losses over the 25-year term of the related debt. For more information about the 2008 Series B GO Zone bonds, see Note 5 — “Debt.”

The following table presents the effect of derivatives designated as hedging instruments on Cleco and Cleco Power’s Condensed Consolidated Statements of Income for the three and nine months ended September 30, 2013 and 2012.



	FOR THE THREE MONTHS ENDED SEPT. 30,
	2013					2012
(THOUSANDS)	AMOUNT OF GAIN RECOGNIZED IN OCI		AMOUNT OF LOSS RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)			AMOUNT OF GAIN RECOGNIZED IN OCI		AMOUNT OF GAIN RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)
Interest rate derivatives ⁽¹⁾	$	—	$	(86	)*	$	802	$	17	*

* The (loss) gain reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.

⁽¹⁾During the three months ended September 30, 2013 and 2012, Cleco had no ineffectiveness and losses related to the interest rate derivatives recorded as a regulatory asset.



	FOR THE NINE MONTHS ENDED SEPT. 30,
	2013					2012
(THOUSANDS)	AMOUNT OF GAIN RECOGNIZED IN OCI		AMOUNT OF LOSS RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)			AMOUNT OF LOSS RECOGNIZED IN OCI			AMOUNT OF LOSS RECLASSIFIED FROM ACCUMULATED OCI INTO INCOME (EFFECTIVE PORTION)
Interest rate derivatives ⁽¹⁾	$	1,762	$	(165	)*	$	(733	)	$	(39	)*

* The loss reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.

⁽¹⁾During the nine months ended September 30, 2013 and 2012, Cleco recorded ineffectiveness and losses related to the interest rate derivatives as a regulatory asset of $3.3 million and $2.6 million, respectively.

At September 30, 2013, Cleco Power expected $0.3 million of the effective portion of deferred net losses related to interest rate derivatives to be reclassed from accumulated OCI to interest charges over the next 12 months.

Note 5 — Debt

Short-term Debt

At September 30, 2013 and December 31, 2012, Cleco and Cleco Power had no short-term debt outstanding.

Long-term Debt

At September 30, 2013, Cleco’s long-term debt outstanding was $1.31 billion, of which $17.1 million was due within one year. The long-term debt due within one year at September 30, 2013, represents $14.9 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $2.2 million of capital lease payments.

For Cleco, long-term debt decreased $40.3 million from December 31, 2012, primarily due to a $75.0 million repayment of senior notes, $60.0 million of solid waste disposal bonds reacquired in March 2013, a $25.0 million reduction in credit facility draws, $14.0 million scheduled Cleco Katrina/Rita storm recovery bond principal payments made in March and September 2013, and a $1.6 million decrease in capital lease



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

obligations. These decreases were partially offset by $35.0 million outstanding on a bank term loan entered into in March 2013, the issuance of $50.0 million 2008 Series A GO Zone bonds and $50.0 million 2008 Series B GO Zone bonds in May 2013, and debt discount amortizations of $0.3 million.

At September 30, 2013, Cleco Power’s long-term debt outstanding was $1.31 billion of which $17.1 million was due within one year. The long-term debt due within one year at September 30, 2013, represents $14.9 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $2.2 million of capital lease payments.

For Cleco Power, long-term debt decreased $15.3 million from December 31, 2012, primarily due to a $75.0 million repayment of senior notes, $60.0 million of solid waste disposal bonds reacquired in March 2013, $14.0 million scheduled Cleco Katrina/Rita storm recovery bond principal payments made in March and September 2013, and a $1.6 million decrease in capital lease obligations. These decreases were partially offset by $35.0 million outstanding on a bank term loan entered into in March 2013, the issuance of $50.0 million 2008 Series A GO Zone bonds and $50.0 million 2008 Series B GO Zone bonds in May 2013, and debt discount amortizations of $0.3 million.

Cleco Power’s $60.0 million solid waste disposal facility bonds due 2037, which were issued by the Rapides Finance Authority for the benefit of Cleco Power in November 2007, were required to be mandatorily tendered by the bondholders for purchase on March 1, 2013, pursuant to the terms of the indenture. The bonds were issued in connection with a loan agreement between the Rapides Finance Authority and Cleco Power. On March 1, 2013, Cleco Power purchased all $60.0 million outstanding bonds at face value plus $1.6 million of accrued interest, using draws under Cleco Power’s revolving credit facility. In connection with the purchase, the interest rate of the bonds will reset each week based on the Securities Industry and Financial Markets Association index. The initial interest rate of the bonds at March 1, 2013, was 0.11% per annum. Interest expense will continue to be recorded with a corresponding amount recorded as interest income, excluding amortization of debt issuance costs. Although the bonds remain outstanding, Cleco Power has the right to redeem and cancel the debt at any time without approval of the Rapides Finance Authority. In accordance with the authoritative guidance, the bonds are considered extinguished and Cleco Power is holding the debt as treasury bonds, resulting in a net presentation on Cleco and Cleco Power's Condensed Consolidated Balance Sheets. Cleco Power has the option to remarket the bonds for new terms and new interest rates, both to be determined by market conditions.

On March 20, 2013, Cleco Power entered into a bank term loan agreement in the amount of $60.0 million. Proceeds of the loan agreement were used to repay draws under Cleco Power’s revolving credit facility. Cleco Power made a $25.0 million payment on the loan on May 8, 2013, reducing the balance outstanding to $35.0 million. The interest rate under the agreement at September 30, 2013, was 0.93%. The rate resets monthly at one month LIBOR, plus 0.75%. The loan matures on May 29, 2015.

subject to remarketing on May 3, 2015. Of the $50.0 million bonds, $25.0 million of the proceeds were used to fund the partial repayment of the $60.0 million solid waste disposal bonds described above and $25.0 million of the proceeds were used to partially fund the maturity of Cleco Power’s $75.0 million 5.375% senior notes on May 1, 2013.

On May 8, 2013, Cleco Power remarketed $50.0 million of its 2008 Series B GO Zone bonds which had previously been purchased by Cleco Power and were being held as treasury bonds, at a fixed interest rate of 4.25%. The 2008 Series B GO Zone bonds mature on December 1, 2038. The proceeds were used to partially fund the maturity of Cleco Power's $75.0 million 5.375% senior notes on May 1, 2013.

Credit Facilities

At September 30, 2013, Cleco Corporation and Cleco Power had no borrowings outstanding under their respective existing $250.0 million and $300.0 million credit facilities.

On October 16, 2013, Cleco Corporation and Cleco Power entered into new, amended and restated credit facilities with a maturity date of October 16, 2018. The new facilities replace the previous facilities, which were to mature on October 7, 2016. The new facilities are comprised of the same ten banks, plus one additional bank. The new facilities are priced the same as the old facilities and are for the same amounts.

Note 6 — Pension Plan and Employee Benefits

Pension Plan and Other Benefits Plan

Most employees hired before August 1, 2007, are covered by a non-contributory, defined benefit pension plan. Benefits under the plan reflect an employee’s years of service, age at retirement, and highest total average compensation for any consecutive five calendar years during the last ten years of employment with Cleco. Cleco’s policy is to base its contributions to the employee pension plan upon actuarial computations utilizing the projected unit credit method, subject to the IRS’s full funding limitation. In January 2013, Cleco Power made $34.0 million in discretionary contributions to the pension plan designated for the 2012 plan year. Cleco does not expect to make any additional discretionary contributions to the pension plan for the remainder of the year. During 2012, Cleco made no discretionary or required contributions to the pension plan. 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, 2013 and 2012, are as follows:



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



	PENSION BENEFITS						OTHER BENEFITS
	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013			2012			2013		2012
Components of periodic benefit cost:
Service cost	$	2,472		$	2,078		$	614	$	303
Interest cost	4,485			4,563			214		334
Expected return on plan assets	(5,861		)	(5,201		)	—		—
Amortizations:
Transition obligation	—			—			6		5
Prior period service credit	(18		)	(18		)	—		—
Net loss	3,304			2,087			213		112
Net periodic benefit cost	$	4,382		$	3,509		$	1,047	$	754



	PENSION BENEFITS						OTHER BENEFITS
	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013			2012			2013		2012
Components of periodic benefit cost:
Service cost	$	7,417		$	6,234		$	1,242	$	1,096
Interest cost	13,455			13,690			1,176		1,287
Expected return on plan assets	(17,584		)	(15,604		)	—		—
Amortizations:
Transition obligation	—			—			15		15
Prior period service credit	(53		)	(53		)	—		—
Net loss	9,913			6,259			849		512
Net periodic benefit cost	$	13,148		$	10,526		$	3,282	$	2,910

Because Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power. The liability of Cleco’s other subsidiaries is transferred with a like amount of assets to Cleco Power monthly. The expense of the pension plan related to Cleco’s other subsidiaries for the three and nine months ended September 30, 2013, was $0.6 million and $1.9 million, respectively. The amounts for the same periods in 2012 were $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, 2013. The amount at December 31, 2012, was also $3.1 million. The current portion of the other benefits liability for Cleco Power was $2.9 million at September 30, 2013. The amount at December 31, 2012, 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, 2013, was $0.9 million and $2.8 million, respectively. The amounts for the same periods in 2012 were $0.7 million and $2.5 million, respectively.

SERP

Certain Cleco 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 plus 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, because SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco Power in the event of insolvency. All SERP benefits are paid out of the general cash available of the respective companies from which the officer retired. No contributions to the SERP were made during the nine months ended September 30, 2013 or 2012. Cleco Power is considered the plan sponsor and Support Group is considered the plan administrator. The components of net periodic SERP benefit cost for the three and nine months ended September 30, 2013 and 2012, are as follows:



	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013		2012		2013		2012
Components of periodic benefit cost:
Service cost	$	514	$	372	$	1,541	$	1,115
Interest cost	645		632		1,934		1,895
Amortizations:
Prior period service cost	13		13		40		40
Net loss	576		441		1,728		1,324
Net periodic benefit cost	$	1,748	$	1,458	$	5,243	$	4,374

The SERP liabilities are reported on the individual subsidiaries’ financial statements. At September 30, 2013 and December 31, 2012, the current portion of the SERP liability for Cleco was $2.7 million and $2.5 million, respectively. The current portion of the SERP liability for Cleco Power was $0.8 million at September 30, 2013. The amount at December 31, 2012, 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 $1.2 million for the three and nine months ended September 30, 2013, compared to $0.4 million and $1.1 million for the same period in 2012.

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 months ended September 30, 2013 and 2012 is as follows:



	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013		2012		2013		2012
401(k) Plan expense	$	936	$	963	$	3,361	$	3,303

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, 2013, was $0.2 million and $0.8 million, respectively. The amounts for the same periods in 2012 were also $0.2 million and $0.8 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, 2013 and 2012.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
	2013		2012		2013		2012
Cleco	34.1	%	24.0	%	33.0	%	27.8	%
Cleco Power	35.0	%	25.5	%	34.6	%	31.0	%

Effective Tax Rates

For the three and nine months ended September 30, 2013 and 2012, the effective income tax rate for Cleco was different than the federal statutory rate due to permanent tax deductions, flowthrough benefits associated with AFUDC equity, tax benefits delivered from Cleco’s investment in the NMTC Fund, an increase in the liability for uncertain tax positions, a favorable settlement with taxing authorities, adjustments for tax returns as filed, and state tax expense.

For the three and nine months ended September 30, 2013, compared to the three and nine months ended September 30, 2012, the effective income tax rate for Cleco increased due to a decrease in permanent tax deductions, a decrease in flowthrough benefits associated with AFUDC equity, a decrease in tax benefits delivered from Cleco's investment in the NMTC Fund, an increase in the liability for uncertain tax positions, and the absence of a favorable settlement with taxing authorities.

For the three and nine months ended September 30, 2013 and 2012, the effective income tax rate for Cleco Power was different than the federal statutory rate due to permanent tax deductions, flowthrough benefits associated with AFUDC equity, a decrease in the liability for uncertain tax positions, a favorable settlement with taxing authorities, adjustments for tax returns as filed, and state tax expense.

For the three and nine months ended September 30, 2013, compared to the three and nine months ended September 30, 2012, the effective income tax rate for Cleco Power increased due to a decrease in permanent tax deductions, a decrease in flowthrough benefits associated with AFUDC equity, and the absence of a favorable settlement with taxing authorities.

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, 2013 and December 31, 2012, Cleco had a deferred tax asset resulting from NMTC carryforwards of $91.2 million and $78.8 million, respectively. If the NMTC carryforwards are not utilized, they will begin to expire in 2029. Management considers it more likely than not that all deferred tax assets related to NMTC carryforwards will be realized; therefore, no valuation allowance has been recorded.

Net Operating Losses

As of September 30, 2013, Cleco had a net operating loss carryforward primarily related to a tax accounting method change for bonus depreciation associated with Madison Unit 3. Cleco considers it more likely than not that these income tax losses generated will be utilized to reduce future income taxes. Cleco expects to utilize the entire net operating loss carryforward within the statutory deadlines.

Uncertain Tax Positions

Cleco classifies all interest related to uncertain tax positions as a component of interest payable and interest expense. The total amounts of 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, 2013		AT DEC. 31, 2012
Interest payable
Cleco	$	2,069	$	1,420
Cleco Power	$	3,712	$	3,358

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, 2013 and December 31, 2012, are $8.4 million and $6.2 million, respectively.



	FOR THE THREE MONTHS ENDED SEPT. 30,					FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013		2012			2013			2012
Interest charges
Cleco	$	174	$	(121	)	$	(116	)	$	(8,477	)
Cleco Power	$	113	$	133		$	354		$	(9,504	)

The interest charges reflect the amount of interest anticipated to be paid to or received from taxing authorities. These amounts do not include any offset for the amounts that may be recovered from or owed to customers under the existing rate orders.

The federal income tax years that remain subject to examination by the IRS are 2007 through 2012. The Louisiana state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2002 through 2011. At December 31, 2012, Cleco had $60.4 million deposited with the IRS, of which $43.5 million remained to either offset tax and interest liabilities for tax years subsequent to 2003 or to be refunded. Cleco received a refund of tax and interest in January 2013 from the IRS of $42.3 million relating to tax years 2001 through 2008.

Cleco is currently under audit by the IRS for the years 2010 through 2012. During the third quarter of 2013, Cleco increased its liability for uncertain tax positions. In addition, Cleco reclassified all uncertain tax positions to current from noncurrent as it expects to settle all outstanding audits within the next 12 months. Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of September 30, 2013, could decrease by a maximum of $4.6 million for Cleco and the balance for Cleco Power would be unchanged in the next 12 months as a result of reaching settlements with the IRS and state tax authorities. The settlements could involve the payment of additional taxes, the adjustment of deferred taxes, and/or the recognition of tax benefits, which may have an effect on Cleco’s effective tax rate.

Cleco classifies income tax penalties as a component of other expense. During 2013 and 2012, the amount of penalties recognized was immaterial.

Note 8 — Disclosures about Segments

Cleco’s reportable segments are based on its method of internal reporting, which disaggregates business units by its first-tier subsidiary. Cleco’s reportable segments are Cleco Power and Midstream. The holding company, a shared services subsidiary, two transmission interconnection facility



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

subsidiaries, and an investment subsidiary are shown as Other in the following tables.

Each reportable segment engages in business activities from which it earns revenue and incurs expenses. Segment managers report periodically to Cleco’s Chief Executive Officer (the chief operating decision-maker) with discrete financial information and, at least quarterly, present discrete financial information to Cleco Corporation’s Board of Directors. Each reportable segment prepared budgets for 2013 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 the power purchase agreement between Cleco Power and Evangeline that began in 2012 and joint and common administrative support services provided by Support Group.



SEGMENT INFORMATION FOR THE THREE MONTHS ENDED SEPT. 30,
2013 (THOUSANDS)	CLECO POWER			MIDSTREAM		OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	314,766		$	—	$	—		$	—		$	314,766
Tolling operations	—			12,339		—			(12,339		)	—
Other operations	14,301			1		541			—			14,843
Electric customer credits	(846		)	—		—			—			(846		)
Affiliate revenue	335			—		13,313			(13,648		)	—
Operating revenue, net	$	328,556		$	12,340	$	13,854		$	(25,987	)	$	328,763
Depreciation	$	39,962		$	1,522	$	272		$	—		$	41,756
Interest charges	$	18,656		$	312	$	(110	)	$	156		$	19,014
Interest income	$	331		$	—	$	(156	)	$	157		$	332
Federal and state income tax expense (benefit)	$	33,355		$	4,083	$	(3,048	)	$	(1	)	$	34,389
Net income	$	61,885		$	1,164	$	3,358		$	—		$	66,407
Additions to long-lived assets	$	38,585		$	337	$	358		$	—		$	39,280
Equity investment in investees	$	14,532		$	—	$	8		$	1		$	14,541
Total segment assets	$	3,881,391		$	219,028	$	106,158		$	(79,060	)	$	4,127,517



2012 (THOUSANDS)	CLECO POWER			MIDSTREAM			OTHER			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
Net income	$	57,783		$	3,429		$	2,606		$	—		$	63,818
Additions to long-lived assets	$	65,073		$	799		$	503		$	—		$	66,375
Equity investment in investees ⁽¹⁾	$	14,532		$	—		$	8		$	—		$	14,540
Total segment assets⁽¹⁾	$	3,871,729		$	215,342		$	201,678		$	(141,400	)	$	4,147,349
⁽¹⁾Balances as of December 31, 2012



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



SEGMENT INFORMATION FOR THE NINE MONTHS ENDED SEPT. 30,
2013 (THOUSANDS)	CLECO POWER			MIDSTREAM			OTHER			ELIMINATIONS			CONSOLIDATED
Revenue
Electric operations	$	796,957		$	—		$	—		$	—		$	796,957
Tolling operations	—			26,483			—			(26,483		)	—
Other operations	36,366			2			1,550			(1		)	37,917
Electric customer credits	(1,270		)	—			—			—			(1,270		)
Affiliate revenue	1,005			—			40,406			(41,411		)	—
Operating revenue	$	833,058		$	26,485		$	41,956		$	(67,895	)	$	833,604
Depreciation	$	105,251		$	4,523		$	755		$	—		$	110,529
Interest charges	$	60,882		$	(338	)	$	334		$	480		$	61,358
Interest income	$	784		$	—		$	(474	)	$	479		$	789
Federal and state income tax expense (benefit)	$	65,558		$	7,221		$	(5,887	)	$	—		$	66,892
Net income	$	124,142		$	6,180		$	5,251		$	(1	)	$	135,572
Additions to long-lived assets	$	124,731		$	2,664		$	1,629		$	—		$	129,024
Equity investment in investees	$	14,532		$	—		$	8		$	1		$	14,541
Total segment assets	$	3,881,391		$	219,028		$	106,158		$	(79,060	)	$	4,127,517



2012 (THOUSANDS)	CLECO POWER		MIDSTREAM		OTHER			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
Net income	$	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 ⁽¹⁾	$	14,532	$	—	$	8		$	—		$	14,540
Total segment assets ⁽¹⁾	$	3,871,729	$	215,342	$	201,678		$	(141,400	)	$	4,147,349
⁽¹⁾ Balances as of December 31, 2012

Note 9 — Electric Customer Credits

The current amount of Cleco Power’s annual retail earnings is subject to the terms of an FRP established by the LPSC effective February 12, 2010. The FRP allows Cleco Power the opportunity to earn a target return on equity of 10.7%, including returning to retail customers 60% of retail earnings between 11.3% and 12.3% and all retail earnings over 12.3%. The amount of credits due customers, if any, is determined by Cleco Power and the LPSC annually. Cleco Power must file annual monitoring reports no later than October 31 for the 12-month period ending June 30. In April 2013, Cleco Power filed an application with the LPSC to extend its current FRP and seek rate recovery of Coughlin. Cleco Power requested in its application that the FRP extension be effective through June 2020. The docket is currently in the discovery phase. The procedural schedule currently anticipates LPSC testimony by mid-November 2013. Cleco Power expects LPSC action on this request by the second quarter of 2014.

On October 31, 2012, Cleco Power filed its report for the 12 months ended June 30, 2012, which indicated that $1.7 million was due to be returned to customers. On June 26, 2013, the LPSC approved the monitoring report for the 12 months ended June 30, 2012, with a recommended adjusted refund of $2.4 million. The increase in refund was the result of

changes to revenue requirements for certain FRP Rider items. Cleco Power issued refunds on customers’ bills in the third quarter of 2013. Cleco Power expects to file its monitoring report for the 12 months ended June 30, 2013 on or before October 31, 2013, which will indicate that $2.2 million is due to be returned to customers. Cleco Power has accrued for this anticipated refund at September 30, 2013. The accrual for estimated electric customer credits reflected on Cleco Corporation and Cleco Power’s Condensed Consolidated Balance Sheets at September 30, 2013 and December 31, 2012, was $3.0 million and $4.2 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.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

Equity Method VIEs

Equity investment in investees at September 30, 2013, primarily represented Cleco Power’s $14.5 million investment in Oxbow. Equity investments that are less than 100% owned by Diversified Lands represented less than $0.1 million of the total balance.

Oxbow

Oxbow is owned 50% by Cleco Power and 50% by SWEPCO and is accounted for as an equity method investment. Cleco Power is not the primary beneficiary because it shares the power to control Oxbow’s significant activities with SWEPCO. Cleco’s current assessment of its maximum exposure to loss related to Oxbow at September 30, 2013, 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, 2013		AT DEC. 31, 2012
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, 2013		AT DEC. 31, 2012
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, 2013		AT DEC. 31, 2012
Current assets	$	2,182	$	1,814
Property, plant, and equipment, net	22,698		23,029
Other assets	4,254		4,248
Total assets	$	29,134	$	29,091
Current liabilities	$	69	$	26
Partners’ capital	29,065		29,065
Total liabilities and partners’ capital	$	29,134	$	29,091



	FOR THE THREE MONTHS ENDED SEPT. 30,				FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013		2012		2013		2012
Operating revenue	$	856	$	450	$	1,795	$	1,125
Operating expenses	856		450		1,795		1,125
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 PRPs for a contaminated site, and imposes strict, joint, and several liability on those PRPs for the cost of response to the contamination. The special notice requested that Cleco Corporation and Cleco Power, along with many other listed PRPs, enter into negotiations with the EPA for the performance of an RI/FS at an area known as the Devil’s Swamp Lake site just northwest of Baton Rouge, Louisiana. The EPA identified Cleco as one of many companies that was sending PCB wastes for disposal to the site. The Devil’s Swamp Lake site has been proposed to be added to the National Priorities List based on the release of PCBs to fisheries and wetlands located on the site, but no final determination has been made. The PRPs began discussing a potential proposal to the EPA in February 2008. The EPA issued a Unilateral Administrative Order to PRP’s Clean Harbors, Inc. and Baton Rouge Disposal to Conduct an RI/FS on December 3, 2009. The Tier 1 part of the study was complete as of June 25, 2012. Currently, the study/remedy selection task continues. Therefore, management is unable to determine how significant Cleco’s share of the costs associated with the RI/FS and possible response action at the facility site, if any, may be and whether or not this will have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.

Discrimination Complaints

In December 2009, a complaint was filed in the U.S. District Court for the Western District of Louisiana (the Court) on behalf of eight current employees and four former employees alleging that Cleco discriminated against each of them on the basis of race. Each 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. In July 2010, the plaintiffs moved to add an additional current employee alleging that Cleco had discriminated on the basis of race. The additional plaintiff seeks compensation of no less than $2.5 million and became the thirteenth plaintiff. In April 2011, Cleco entered into a settlement with one of the current employees which resulted in a dismissal of one of the thirteen cases with prejudice. In September 2011, the Court ruled on Cleco’s summary judgment motions, with the end result that eleven of the twelve remaining plaintiffs had at least one claim remaining. In February 2013, the Court ruled on the second motion for summary judgment, filed by Cleco in March 2012, in each of the eleven cases and each such case was dismissed with prejudice. Appeals were filed in ten of the eleven dismissed cases to the United States Court of Appeals for the Fifth Circuit (the Fifth Circuit). In June 2013, the Fifth Circuit clerk dismissed the appeals of two of the current employees due to their failure to file a brief in support of their respective appeals. On various dates during August, September, and October 2013, the Fifth Circuit affirmed the trial court



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

judgments in favor of Cleco in six of the eight remaining cases. There has been no disposition of the two remaining appeals.

City of Opelousas

In March 2010, a complaint was filed in the 27th Judicial District Court of St. Landry Parish, State of Louisiana, on behalf of three Cleco Power customers in Opelousas, Louisiana. The complaint alleges that Cleco Power overcharged the plaintiffs by applying to customers in Opelousas the same retail rates as Cleco Power applies to all of its retail customers. The plaintiffs claim that Cleco Power owes customers in Opelousas more than $30.0 million as a result of the alleged overcharges. The plaintiffs allege that Cleco Power should have established, solely for customers in Opelousas, retail rates that are separate and distinct from the retail rates that apply to other customers of Cleco Power and that Cleco Power should not collect from customers in Opelousas the storm surcharge approved by the LPSC following hurricanes Katrina and Rita. In April 2010, Cleco Power filed a petition with the LPSC appealing to its expertise in declaring that the ratepayers of Opelousas have been properly charged the rates that are applicable to Cleco Power’s retail customers and that no overcharges have been collected.

In May 2010, a second class action lawsuit was filed in the 27th Judicial District Court for St. Landry Parish, State of Louisiana, repeating the allegations of the first complaint, which was submitted on behalf of 249 Opelousas residents. In January 2011, the presiding judge in the state court proceeding ruled that the jurisdiction to hear the two class actions resides in the state court and not with the LPSC as argued by both Cleco and the LPSC Staff. Both Cleco and the LPSC Staff appealed this ruling to the Third Circuit Court of Appeals for the State of Louisiana (Third Circuit). In September 2011, the Third Circuit denied both appeals. In October 2011, both Cleco and the LPSC appealed the Third Circuit’s ruling to the Louisiana Supreme Court. In February 2011, the administrative law judge (ALJ) in the LPSC proceeding ruled that the LPSC has jurisdiction to decide the claims raised by the class action plaintiffs. At its December 2011 Business and Executive Session, the LPSC adopted the ALJ’s recommendation that Cleco be granted summary judgment in its declaratory action finding that Cleco’s ratepayers in the City of Opelousas have been served under applicable rates and policies approved by the LPSC and Cleco’s Opelousas ratepayers have not been overcharged in connection with LPSC rates or ratemaking. In January 2012, the class action plaintiffs filed their appeal of such LPSC decision to the 19th Judicial District Court for East Baton Rouge Parish, State of Louisiana. In December 2012, the Louisiana Supreme Court issued its opinion accepting Cleco’s jurisdictional arguments and dismissed the state court claims. The only matter remaining is before the 19th Judicial District Court to review the LPSC ruling in Cleco’s favor that it had properly charged the ratepayers of Opelousas. In view of the uncertainty of the claims, management is not able to predict or give a reasonable estimate of the possible range of liability, if any, of these claims. However, if it is found that Cleco Power overcharged customers resulting in a refund, any such refund could have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

Other

Cleco is involved in various litigation matters, including regulatory, environmental, and administrative proceedings

before various courts, regulatory commissions, arbitrators, and governmental agencies regarding matters arising in the ordinary course of business. The liability Cleco may ultimately incur with respect to any one of these matters in the event of a negative outcome may be in excess of amounts currently accrued. Management regularly analyzes current information and, as of September 30, 2013, believes the probable and reasonably estimable liabilities based on the eventual disposition of these matters is approximately $8.9 million and has accrued this amount.

Off-Balance Sheet Commitments

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

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

The off-balance sheet commitments are not recognized on Cleco’s Condensed Consolidated Balance Sheets because management has determined that Cleco’s affiliates are able to perform these obligations under their contracts and that it is not probable that payments by Cleco will be required. Cleco’s off-balance sheet commitments as of September 30, 2013, 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, 2013
(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.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

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, 2013, 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 limited guarantees and indemnifications were provided to Cleco Power. The maximum amount of the potential payment to Cleco Power for indemnifications was $30.0 million, except for indemnifications relating to the fundamental organizational structure of which there was no maximum amount. Cleco Corporation was obligated to pay a maximum of $10.0 million if the claims were not paid to Cleco Power pursuant to the guarantee. An indemnification liability of $13.5 million which represents the fair value of these indemnifications was recorded on Cleco’s Condensed Consolidated Balance Sheet.

The indemnification liabilities were reduced through expiration of the contractual life or through a reduction in the probability of a claim arising. The indemnification obligation had a term of approximately three years. As these underlying indemnifications expired, income was recognized on Cleco’s Condensed Consolidated Statements of Income. At September 30, 2013, the contractual life of the indemnification had expired and there was no remaining liability. For the three months ended September 30, 2013, less than $0.1 million of income was recognized and for the nine months ended September 30, 2013, $0.4 million was recognized. For the three months ended September 30, 2012, no income was recognized and for the nine months ended September 30, 2012, $7.2 million was recognized.

In April 2011, Acadia completed its disposition of Acadia Unit 2 to Entergy Louisiana. Limited guarantees and indemnifications were provided to Entergy Louisiana and an indemnification liability of $21.8 million, which represents the fair value of these indemnifications was recorded on Cleco’s Condensed Consolidated Balance Sheet.

The indemnification liabilities are reduced through expiration of the contractual life or through a reduction in the probability of a claim arising. The indemnification obligation is expected to have a term of three years. After the three-year period, a residual value of approximately $0.2 million will remain. At September 30, 2013, an indemnification liability of $0.9 million remained, which represents the risk of payment, as a contingent sale obligation recorded on Cleco’s Condensed Consolidated Balance Sheet. As these underlying indemnifications expire, income is recognized on Cleco’s

Condensed Consolidated Statements of Income. For the three months ended September 30, 2013, no income was recognized and for the nine months ended September 30, 2013, $6.9 million was recognized. For the three months ended September 30, 2012, no income was recognized and for the nine months ended September 30, 2012, $11.8 million was recognized. The maximum amount of the potential payment to Entergy Louisiana for the indemnifications is the purchase price of $298.8 million, except for the liabilities retained for which there is no maximum amount. Cleco Corporation is obligated to pay the same maximum amounts as Acadia if Acadia is unable to pay claims to Entergy Louisiana pursuant to the guarantee.

As part of the Amended Lignite Mining Agreement, Cleco Power and SWEPCO, joint owners of Dolet Hills, have agreed to pay the loan and lease principal obligations of the lignite miner, DHLC, when due if they do not have sufficient funds or credit to pay. Any amounts paid on behalf of the miner would be credited by the lignite miner against future invoices for lignite delivered. At September 30, 2013, 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 amount of commitment termination per period of off-balance sheet commitments and on-balance sheet guarantees discussed above.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



							AT SEPT. 30, 2013
			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	4,906		900		—		—		4,006
Total	$	9,131	$	4,625	$	—	$	—	$	4,506

Other Commitments

NMTC Fund

In 2008, Cleco Corporation and US Bancorp Community Development Corporation (USBCDC) formed the NMTC Fund. Cleco has a 99.9% membership interest in the NMTC Fund and USBCDC has a 0.1% interest. The purpose of the NMTC Fund is to invest in projects located in qualified active low-income communities that are underserved by typical debt capital markets. These investments are designed to generate NMTCs and Historical Rehabilitation tax credits. The NMTC Fund was later amended to include renewable energy investments. The majority of the energy investments qualify for grants under Section 1603 of the 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 $283.6 million of equity contributions to the NMTC Fund and will receive at least $301.9 million in the form of tax credits, tax losses, capital gains/losses, earnings, and cash over the life of the investment, which ends in 2017. The $18.3 million difference between equity contributions and total benefits received will be recognized over the life of the NMTC Fund as net tax benefits are delivered. The following table reflects remaining future equity contributions.



(THOUSANDS)	CONTRIBUTION
Three months ending Dec. 31, 2013	$	12,071
Years ending Dec. 31,
2014	47,434
2015	11,195
2016	3,698
2017	2,914
Total	$	77,312

Of the $77.3 million, $48.3 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, 2013, was $83.4 million. The amount of tax benefits delivered but not utilized as of September 30, 2013, was $112.3 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:	$	77,312
Less: unamortized discount	5,015
Total	$	72,297

The gross investment amortization expense will be recognized over a ten-year period, with four years remaining under the new amendment, using the cost method in accordance with the authoritative guidance for investments. The grants received under Section 1603, which allow certain projects to receive a federal grant in lieu of tax credits, and other cash reduce the basis of the investment. Periodic amortization of the investment and the deferred taxes generated by the basis reduction temporary difference are included as components of income tax expense.

Other

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

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

Future actions or inactions of the U.S. federal government, including a failure to increase the government debt limit or another shutdown of the federal government, could increase the actual or perceived risk that the U.S. may not ultimately pay its obligations when due and may disrupt financial markets, including capital markets.

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 CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

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 or S&P, Cleco Power would be required to pay additional fees and higher interest rates under its bank credit agreements. Cleco Power’s collateral for derivatives is based on the lowest rating held. If Cleco Power’s credit ratings were to be downgraded by Moody’s or S&P, Cleco Power would be required to pay additional collateral for derivatives.

Note 12 — Affiliate Transactions

Cleco Power has affiliate balances that are payable to or due from its affiliates. The following table is a summary of those balances.



	AT SEPT. 30, 2013				AT DEC. 31, 2012
(THOUSANDS)	ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE		ACCOUNTS RECEIVABLE		ACCOUNTS PAYABLE
Cleco Corporation	$	5	$	368	$	139	$	1,140
Support Group	1,160		6,415		2,777		7,528
Midstream	63		2		27		5
Evangeline	21		3,371		6		1,401
Diversified Lands	10		84		42		23
Other ⁽¹⁾	1		—		—		—
Total	$	1,260	$	10,240	$	2,991	$	10,097
⁽¹⁾ Represents Perryville and Attala

Note 13 — 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 cost of restoration for Hurricane Isaac was $24.3 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 56.0% of the restoration costs recorded at September 30, 2013, or approximately $13.6 million. The remaining cost was offset against Cleco Power’s existing storm damage reserve.



Note 14 — Accumulated Other Comprehensive Loss

The components of accumulated other comprehensive loss are summarized in the following tables for Cleco and Cleco Power. All amounts are reported net of income taxes and amounts in parentheses indicate debits.



Cleco
				FOR THE THREE MONTHS ENDED SEPT. 30, 2013
(THOUSANDS)	POSTRETIREMENT BENEFIT NET (LOSS) GAIN			NET (LOSS) GAIN ON CASH FLOW HEDGES			TOTAL ACCUMULATED OTHER COMPREHENSIVE (LOSS) GAIN
Balances, June 30, 2013	$	(23,619	)	$	(6,256	)	$	(29,875	)
Amounts reclassified from accumulated other comprehensive income:
Amortization of postretirement benefit net loss	497			—			497
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive income	497			53			550
Balances, Sept. 30, 2013	$	(23,122	)	$	(6,203	)	$	(29,325	)



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



				FOR THE NINE MONTHS ENDED SEPT. 30, 2013
(THOUSANDS)	POSTRETIREMENT BENEFIT NET (LOSS) GAIN			NET (LOSS) GAIN ON CASH FLOW HEDGES			TOTAL ACCUMULATED OTHER COMPREHENSIVE (LOSS) GAIN
Balances, Dec. 31, 2012	$	(24,741	)	$	(7,629	)	$	(32,370	)
Other comprehensive income before reclassifications:
Net derivative gain	—			1,355			1,355
Amounts reclassified from accumulated other comprehensive income:
Amortization of postretirement benefit net loss	1,619			—			1,619
Reclassification of net loss to interest charges	—			102			102
Reclassification of ineffectiveness to regulatory asset	—			(31		)	(31		)
Net current-period other comprehensive income	1,619			1,426			3,045
Balances, Sept. 30, 2013	$	(23,122	)	$	(6,203	)	$	(29,325	)



Cleco Power
				FOR THE THREE MONTHS ENDED SEPT. 30, 2013
(THOUSANDS)	POSTRETIREMENT BENEFIT NET (LOSS) GAIN			NET (LOSS) GAIN ON CASH FLOW HEDGES			TOTAL ACCUMULATED OTHER COMPREHENSIVE (LOSS) GAIN
Balances, June 30, 2013	$	(12,272	)	$	(6,256	)	$	(18,528	)
Amounts reclassified from accumulated other comprehensive income:
Amortization of postretirement benefit net loss	207			—			207
Reclassification of net loss to interest charges	—			53			53
Net current-period other comprehensive income	207			53			260
Balances, Sept. 30, 2013	$	(12,065	)	$	(6,203	)	$	(18,268	)



				FOR THE NINE MONTHS ENDED SEPT. 30, 2013
(THOUSANDS)	POSTRETIREMENT BENEFIT NET (LOSS) GAIN			NET (LOSS) GAIN ON CASH FLOW HEDGES			TOTAL ACCUMULATED OTHER COMPREHENSIVE (LOSS) GAIN
Balances, Dec. 31, 2012	$	(12,792	)	$	(7,629	)	$	(20,421	)
Other comprehensive income before reclassifications:
Net derivative gain	—			1,355			1,355
Amounts reclassified from accumulated other comprehensive income:
Amortization of postretirement benefit net loss	727			—			727
Reclassification of net loss to interest charges	—			102			102
Reclassification of ineffectiveness to regulatory asset	—			(31		)	(31		)
Net current-period other comprehensive income	727			1,426			2,153
Balances, Sept. 30, 2013	$	(12,065	)	$	(6,203	)	$	(18,268	)



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

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

Cleco uses its website, http:\\www.cleco.com, as a routine channel for distribution of important information, including news releases, analyst presentations, and financial information. Cleco’s website is the primary source of publicly disclosed news about Cleco. Cleco is providing the address to its website solely for the information of investors and does not intend the address to be an active link. The contents of the website are not incorporated into this Combined Quarterly Report on Form 10-Q.

The following discussion and analysis should be read in combination with the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2012, 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, 2013 and September 30, 2012.

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 2,565 MW and serves approximately 283,000 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). Evangeline owns two generating units with a total nameplate capacity of 775 MW.

Cleco Power

Many factors affect Cleco Power’s primary business of selling electricity. These factors include the presence of a stable regulatory environment, which impacts 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 completion of the AMI project, implementation of various environmental controls to comply with the MATS ruling, completion of the transfer of ownership and control of Coughlin from Evangeline, extension of its current FRP, and integration into MISO. These initiatives are discussed below.

AMI Project

remaining $52.4 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 allows Cleco Power to better manage its electric system and provides improved service to customers through the meter’s communicating capabilities. At September 30, 2013, Cleco Power had incurred $69.7 million in project costs, of which $20.0 million has been reimbursed by the DOE. The installation of the advanced meters was substantially completed in May 2013, with the project to be fully functional by the fourth quarter of 2013. For more information on the AMI Project, see “— Financial Condition — Regulatory and Other Matters — AMI Project.”

MATS

The MATS rule was finalized in February 2012 and requires affected electric generating units to meet specific numeric emission standards and work practice standards to address hazardous air pollutants. MATS imposes strict emission limits on new and existing coal- and liquid oil-fired electric generating units for mercury, acid gases, and non-mercury metallic pollutants. Cleco Power units impacted by the rule include Rodemacher Unit 2, Madison Unit 3, and Dolet Hills. MATS allows existing sources approximately three years to comply with the rule. The actual compliance deadline is April 16, 2015. Cleco Power completed its evaluation of control technology options and has identified capital expenditures that will be required to engineer, procure, and install pollution controls and emissions monitoring equipment to ensure Cleco Power will be in a position to comply with MATS in a timely manner. New equipment to be installed and operational by the compliance date at Rodemacher Unit 2 and Dolet Hills includes dry sorbent injection for acid gas control and fabric filters (baghouses) for metal particulate control. In addition, activated carbon injection for mercury control is to be installed and operational by the compliance date at Rodemacher Unit 2, Madison Unit 3, and Dolet Hills. Cleco Power has completed the design work for this equipment and work has been initiated at both Dolet Hills and Rodemacher Unit 2, with work at Madison Unit 3 expected to begin in the second quarter of 2014. Cleco Power filed an application with the LPSC on August 16, 2012, requesting authorization to recover the revenue requirements associated with the MATS equipment. The LPSC proceeding is currently in the discovery phase. The MATS project is expected to cost $265.0 million, of which Cleco Power’s portion is $111.3 million. As of September 30, 2013, $83.3 million was spent on the project, of which Cleco Power’s portion was $35.0 million.

Power Supply Options/Coughlin Transfer from Midstream

Cleco Power issued an RFP seeking up to approximately 750 MW of capacity and energy, for a three- or five-year period 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 from



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

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. In December 2012, Cleco Power and Evangeline executed definitive agreements to transfer ownership and control of Coughlin from Evangeline to Cleco Power. Cleco Power's application seeking regulatory approval was listed in the LPSC's Official Bulletin, dated April 12, 2013. In May 2013, Cleco Power filed its application with FERC seeking authorization to acquire Coughlin, and subsequently received authorization from FERC on August 26, 2013. The transaction is expected to close on or before April 30, 2014, following regulatory approval by the LPSC.

Extension of FRP

On April 26, 2013, Cleco Power filed an application with the LPSC to extend its current FRP and to seek rate recovery of Coughlin. Cleco Power requested in its application that the FRP extension be effective through June 2020. The docket is currently in the discovery phase. The procedural schedule currently anticipates LPSC testimony by mid-November 2013. Cleco expects LPSC action on this request by the second quarter of 2014.

MISO

Cleco Power’s transmission system is heavily interconnected with Entergy’s system; therefore, Cleco Power plans to follow Entergy and join MISO in December 2013. On December 6, 2012, Cleco Power filed an application with the LPSC indicating Cleco’s intent to join MISO, asking the commission to find that transferring control of certain transmission assets to MISO is in the public interest, to create an accounting order deferring costs related to Cleco Power’s transition into the MISO market, and to expedite treatment. On June 26, 2013, the LPSC unanimously approved Cleco Power’s change of control request. On June 18, 2013, Cleco Power filed a related application with the LPSC requesting approval of Cleco Power’s proposed MISO integration, implementation, and ratemaking plans. Discovery related to this integration, implementation, and ratemaking phase is still ongoing with a vote anticipated from the LPSC in mid-November 2013.

Cleco Midstream

Evangeline

In December 2011, Evangeline was 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 was marketing Coughlin’s capacity for periods beginning after April 30, 2015, and had 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. In December 2012, Cleco Power and Evangeline executed definitive agreements to transfer ownership and control of Coughlin from Evangeline to Cleco Power. For more information, see “— Financial Condition — Regulatory and Other Matters — Generation RFP.”

Comparison of the Three Months Ended September 30, 2013 and 2012



Cleco Consolidated
	FOR THE THREE MONTHS ENDED SEPT. 30,
					FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2013		2012			VARIANCE			CHANGE
Operating revenue, net	$	328,763	$	297,372		$	31,391		10.6	%
Operating expenses	211,969		194,025			(17,944		)	(9.2	)%
Operating income	$	116,794	$	103,347		$	13,447		13.0	%
Allowance for other funds used during construction	$	1,303	$	1,882		$	(579	)	(30.8	)%
Other income	$	2,837	$	1,834		$	1,003		54.7	%
Interest charges	$	19,014	$	21,966		$	2,952		13.4	%
Federal and state income taxes	$	34,389	$	20,179		$	(14,210	)	(70.4	)%
Net income applicable to common stock	$	66,407	$	63,818		$	2,589		4.1	%

Consolidated net income applicable to common stock increased $2.6 million, or 4.1%, in the third quarter of 2013 compared to the third quarter of 2012 primarily due to higher Cleco Power and corporate earnings, partially offset by lower Midstream earnings.

Operating revenue, net increased $31.4 million, or 10.6%, in the third quarter of 2013 compared to the third quarter of 2012 largely as a result of higher base revenue and fuel cost recovery revenue at Cleco Power.

Operating expenses increased $17.9 million, or 9.2%, in the third quarter of 2013 compared to the third quarter of 2012 primarily due to higher per unit costs and volumes of fuel used for electric generation, higher depreciation expense, and higher taxes other than income taxes at Cleco Power. These increases were partially offset by lower recoverable and nonrecoverable purchased power at Cleco Power.

Allowance for other funds used during construction decreased $0.6 million, or 30.8%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to lower AFUDC accruals related to miscellaneous transmission projects at Cleco Power.

Other income increased $1.0 million, or 54.7%, during the third quarter of 2013 compared to the third quarter of 2012 largely due to a death benefit recognized on life insurance policies, partially offset by a decrease in the cash surrender value of life insurance polices and lower mutual assistance income.

Interest charges decreased $3.0 million, or 13.4%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to an adjustment to customer surcredits due to a tax settlement and the retirement of senior notes at Cleco Power.

Federal and state income taxes increased $14.2 million, or 70.4%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to $6.7 million for the change in pre-tax income excluding AFUDC equity, $3.9 million for a decrease in tax credits, $2.9 million for the absence of a favorable 2012 settlement with taxing authorities, $1.7 million for the increase in the liability for uncertain tax positions, and $0.2 million for a decrease in permanent tax deductions. These decreases were partially offset by $0.8 million for adjustments for tax returns filed and $0.4 million for miscellaneous tax items.

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



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



Cleco Power
	FOR THE THREE MONTHS ENDED SEPT. 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2013			2012				VARIANCE			CHANGE
Operating revenue
Base	$	197,905		$	180,276			$	17,629		9.8	%
Fuel cost recovery	116,861			102,618				14,243			13.9	%
Electric customer credits	(846		)	(930		)		84			9.0	%
Other operations	14,301			14,905				(604		)	(4.1	)%
Affiliate revenue	335			343				(8		)	(2.3	)%
Operating revenue, net	328,556			297,212				31,344			10.5	%
Operating expenses
Recoverable fuel used for electric generation	101,004			78,902				(22,102		)	(28.0	)%
Recoverable power purchased for utility customers	15,848			23,706				7,858			33.1	%
FAC non-recoverable fuel and power purchased	3,239			10,347				7,108			68.7	%
Other operations	28,471			29,063				592			2.0	%
Maintenance	17,478			16,095				(1,383		)	(8.6	)%
Depreciation	39,962			33,199				(6,763		)	(20.4	)%
Taxes other than income taxes	10,891			8,390				(2,501		)	(29.8	)%
Total operating expenses	216,893			199,702				(17,191		)	(8.6	)%
Operating income	$	111,663		$	97,510			$	14,153		14.5	%
Allowance for other funds used during construction	$	1,303		$	1,882			$	(579	)	(30.8	)%
Other income	$	2,838		$	1,188			$	1,650		138.9	%
Other expense	$	2,239		$	1,224			$	(1,015	)	(82.9	)%
Interest charges	$	18,656		$	21,962			$	3,306		15.1	%
Federal and state income taxes	$	33,355		$	19,740			$	(13,615	)	(69.0	)%
Net income	$	61,885		$	57,783			$	4,102		7.1	%

Cleco Power’s net income in the third quarter of 2013 increased $4.1 million, or 7.1%, compared to the third quarter of 2012. Contributing factors include:


•	higher base revenue,


•	lower FAC non-recoverable fuel and power purchased,


•	lower interest charges, and


•	higher other income.

These factors were partially offset by:


•	higher income taxes,


•	higher depreciation expense,


•	higher taxes other than income taxes,


•	higher maintenance expenses,


•	higher other expense,


•	lower other operations revenue, and


•	lower allowance for other funds used during construction.



	FOR THE THREE MONTHS ENDED SEPT. 30,
(MILLION kWh)	2013		2012		FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	1,198		1,202		(0.3	)%
Commercial	793		784		1.1	%
Industrial	592		582		1.7	%
Other retail	35		36		(2.8	)%
Total retail	2,618		2,604		0.5	%
Sales for resale	643		616		4.4	%
Unbilled	(45	)	(69	)	34.8	%
Total retail and wholesale customer sales	3,216		3,151		2.1	%



	FOR THE THREE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013			2012			FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	100,636		$	96,954		3.8	%
Commercial	52,678			50,145			5.1	%
Industrial	23,875			21,993			8.6	%
Other retail	2,799			2,669			4.9	%
Surcharge	8,205			1,950			320.8	%
Other	(1,563		)	(1,566		)	0.2	%
Total retail	186,630			172,145			8.4	%
Sales for resale	13,657			12,459			9.6	%
Unbilled	(2,382		)	(4,328		)	45.0	%
Total retail and wholesale customer sales	$	197,905		$	180,276		9.8	%

Cleco Power’s residential customers’ demand for electricity is affected largely by weather. Weather generally is measured in cooling-degree days and heating-degree days. A cooling-degree day is an indication of the likelihood that a consumer will use air conditioning, while a heating-degree day is an indication of the likelihood that a consumer will use heating. An increase in heating-degree days does not produce the same increase in revenue as an increase in cooling-degree days, because alternative heating sources are more available and 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,
				2013 CHANGE
	2013	2012	NORMAL	PRIOR YEAR		NORMAL
Cooling-degree days	1,633	1,560	1,511	4.7	%	8.1	%

Base

Base revenue increased $17.6 million, or 9.8%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to an annual rate adjustment associated with Cleco’s FRP, which resulted in an approximate $6.6 million increase to base revenue, and an adjustment to customer surcredits and increased sales from warmer weather, which resulted in an approximate $11.0 million increase to base revenue.

Cleco Power expects to begin providing service to expansions of current customers’ operations, as well as



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

service to new retail customers. These expansions of service to current customers and service to new customers are expected to contribute additional base revenue of $0.6 million for the remainder of 2013, an additional $2.5 million in 2014, and an additional $3.0 million in 2015. Cleco Power also anticipates additional base revenue for the remainder of 2013 of approximately $1.8 million associated with the implementation of a FERC formula rate methodology for transmission services and $0.5 million associated with the recovery of expenditures for compliance with anticipated environmental laws.

During the third quarter of 2013, Cleco Power executed a 10-year agreement and a 20-year agreement with two existing wholesale customers. The anticipated increase in base revenue related to these customers is approximately $5.2 million in 2014 and an additional $0.5 million in 2015.

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, 2012.

Fuel Cost Recovery

Fuel cost recovery revenue billed to customers increased $14.2 million, or 13.9%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to increases in the per-unit cost of fuel used for electric generation and power purchased for utility customers. Also contributing to the increase were higher volumes of fuel used for electric generation. Partially offsetting the increase were lower 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 FAC, which enables Cleco Power to pass on to its customers substantially all such charges. Approximately 88% of Cleco Power’s total fuel cost during the third quarter of 2013 was regulated by the LPSC, while the remainder was regulated by FERC. Recovery of FAC costs is subject to refund until approval is received from the LPSC.

Other Operations

Other operations revenue decreased $0.6 million, or 4.1%, in the third quarter of 2013 compared to the third quarter of 2012 primarily due to $4.3 million of lower wholesale sales. This decrease was partially offset by $3.6 million of additional transmission revenue as a result of the implementation of new transmission rates and $0.1 million of higher other miscellaneous revenue.

Operating Expenses

Operating expenses increased $17.2 million, or 8.6%, in the third quarter of 2013 compared to the third quarter of 2012. Recoverable fuel used for electric generation increased $22.1 million, or 28.0%, primarily due to higher per unit costs and volumes of fuel used for electric generation as compared to the third quarter of 2012. Recoverable power purchased for utility customers decreased $7.9 million, or 33.1%, largely due to lower volumes of purchased power. Partially offsetting this decrease were higher per unit costs 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. FAC non-recoverable fuel and power purchased decreased $7.1 million, or 68.7%, primarily due to lower non-recoverable wholesale power purchases. Other operations expense decreased $0.6 million, or 2.0%, primarily due to lower customer service expenses and lower generation expenses, partially offset by higher consulting expenses. Maintenance expense increased $1.4 million, or 8.6%, primarily due to higher generating station outage expenses. Depreciation expense increased $6.8 million, or 20.4%, primarily due to amortization of the Evangeline capacity costs and normal recurring additions to fixed assets. Taxes other than income taxes increased $2.5 million, or 29.8%, primarily due to higher property taxes.

Allowance for Other Funds Used During Construction

Allowance for other funds used during construction decreased $0.6 million, or 30.8%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to lower AFUDC accruals resulting from the completion of miscellaneous transmission projects.

Other Income

Other income increased $1.7 million, or 138.9%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to $2.3 million of a death benefit recognized on life insurance policies and $0.1 of higher miscellaneous income, partially offset by $0.7 million of lower mutual assistance income.

Other Expense

Other expense increased $1.0 million, or 82.9%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to a decrease in the cash surrender value of life insurance policies of $1.9 million related to the death benefit recognized, partially offset by $0.8 million of lower mutual assistance expenses and $0.1 million of lower miscellaneous expenses.

Interest Charges

Interest charges decreased $3.3 million, or 15.1%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to $2.1 million related to an adjustment to customer surcredits due to a tax settlement, $1.0 million due to the retirement of senior notes, $0.8 million related to reacquired debt, and $0.1 million of miscellaneous interest charges. These amounts were partially offset by an increase of $0.7 million related to GO Zone bonds.

Income Taxes

Federal and state income taxes increased $13.6 million, or 69.0%, during the third quarter of 2013 compared to the third quarter of 2012. The increase is primarily due to $7.0 million for the change in pre-tax income excluding AFUDC equity, $2.9 million for the absence of a favorable 2012 settlement with taxing authorities, $1.7 million for the absence of a favorable adjustment for tax credits, $1.6 million to record tax expense at the projected annual effective rate, $0.5 million for adjustments for tax returns filed, and $0.1 million for a decrease in permanent tax deductions. These increases were partially offset by $0.2 million for a decrease in the liability for uncertain tax positions.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



Midstream
	FOR THE THREE MONTHS ENDED SEPT. 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2013			2012			VARIANCE			CHANGE
Operating revenue
Tolling operations	$	12,339		$	13,890		$	(1,551	)	(11.2	)%
Other operations	1			1			—			—	%
Operating revenue	12,340			13,891			(1,551		)	(11.2	)%
Operating expenses
Other operations	1,869			2,027			158			7.8	%
Maintenance	2,844			3,903			1,059			27.1	%
Depreciation	1,522			1,499			(23		)	(1.5	)%
Taxes other than income taxes	621			612			(9		)	(1.5	)%
Gain on sale of assets	(29		)	(2		)	27			*
Total operating expenses	6,827			8,039			1,212			15.1	%
Operating income	$	5,513		$	5,852		$	(339	)	(5.8	)%
Federal and state income tax expense	$	4,083		$	2,489		$	(1,594	)	(64.0	)%
Net income	$	1,164		$	3,429		$	(2,265	)	(66.1	)%
* Not meaningful

Factors affecting Midstream during the third quarter of 2013 are described below.

Operating Revenue

Operating revenue decreased $1.6 million, or 11.2%, in the third quarter of 2013 compared to the third quarter of 2012 primarily due to lower tolling revenue at Evangeline resulting from lower variable operations and maintenance and start-up revenue.

Operating Expenses

Operating expenses decreased $1.2 million, or 15.1%, in the third quarter of 2013 compared to the third quarter of 2012 primarily due to lower routine maintenance expenses and lower turbine maintenance expenses at Evangeline.

Income Taxes

Federal and state income taxes increased $1.6 million, or 64.0%, during the third quarter of 2013 compared to the third quarter of 2012 primarily due to $1.9 million for an increase in the liability for uncertain tax positions, partially offset by $0.3 million for the change in pre-tax income.

Comparison of the Nine Months Ended September 30, 2013 and 2012



Cleco Consolidated
			FOR THE NINE MONTHS ENDED SEPT. 30,
						FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2013			2012		VARIANCE			CHANGE
Operating revenue, net	$	833,604		$	760,265	$	73,339		9.6	%
Operating expenses	583,587			528,381		(55,206		)	(10.4	)%
Operating income	$	250,017		$	231,884	$	18,133		7.8	%
Interest income	$	789		$	163	$	626		384.0	%
Allowance for other funds used during construction	$	2,880		$	4,298	$	(1,418	)	(33.0	)%
Other income	$	12,282		$	24,223	$	(11,941	)	(49.3	)%
Other expense	$	2,146		$	2,718	$	572		21.0	%
Interest charges	$	61,358		$	63,205	$	1,847		2.9	%
Federal and state income taxes	$	66,892		$	54,110	$	(12,782	)	(23.6	)%
Net income applicable to common stock	$	135,572		$	140,536	$	(4,964	)	(3.5	)%

Consolidated net income applicable to common stock decreased $5.0 million, or 3.5%, in the first nine months of 2013 compared to the first nine months of 2012 primarily due to lower Midstream and corporate earnings, partially offset by higher earnings at Cleco Power.

Operating revenue, net increased $73.3 million, or 9.6%, in the first nine months of 2013 compared to the first nine months of 2012 largely as a result of higher base revenue and higher fuel cost recovery revenue at Cleco Power.

Operating expenses increased $55.2 million, or 10.4%, in the first nine months of 2013 compared to the first nine months of 2012 primarily due to higher per unit costs and volumes of fuel used for electric generation, higher depreciation expense, higher taxes other than income taxes, and higher operations and maintenance expenses at Cleco Power. These increases were partially offset by lower purchased power costs at Cleco Power.

Interest income increased $0.6 million, or 384.0%, in the first nine months of 2013 compared to the first nine months of 2012 primarily due to interest associated with the deferral of regulatory costs to be collected from customers in future periods.

Allowance for other funds used during construction decreased $1.4 million, or 33.0%, in the first nine months of 2013 compared to the first nine months of 2012 primarily due to lower AFUDC accruals related to miscellaneous transmission projects at Cleco Power.

Other income decreased $11.9 million, or 49.3%, in the first nine months of 2013 compared to the first nine months of 2012 largely due to lower income related to the contractual expiration of underlying indemnifications resulting from the disposition of Acadia Units 1 and 2 . Also contributing to this decrease was a reduction of the cash surrender value of life insurance policies related to the death benefit recognized and lower mutual assistance income, partially offset by a death benefit recognized on life insurance policies.

Other expense decreased $0.6 million, or 21.0%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to lower mutual assistance expenses.

Interest charges decreased $1.8 million, or 2.9%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to an adjustment to customer surcredits



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

due to a tax settlement and lower interest on bonds, partially offset by a change in uncertain tax positions.

Federal and state income taxes increased $12.8 million, or 23.6%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to $5.2 million for a decrease in tax credits, $3.5 million for the change in pre-tax income excluding AFUDC equity, $1.7 million for the increase in the liability for uncertain tax positions, $1.6 million for the absence of a favorable 2012 settlement with taxing authorities, $1.1 million for a decrease in permanent tax deductions, and $0.9 million for a decrease in flowthrough of tax benefits. These increases were partially offset by $0.6 million for adjustments for tax returns filed, $0.3 million to record tax expense at the consolidated projected annual effective tax rate, and $0.3 million for miscellaneous tax items.

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



Cleco Power
				FOR THE NINE MONTHS ENDED SEPT. 30,
								FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2013				2012			VARIANCE			CHANGE
Operating revenue
Base	$	496,138			$	465,800		$	30,338		6.5	%
Fuel cost recovery	300,819				254,976			45,843			18.0	%
Electric customer credits	(1,270		)		1,025			(2,295		)	(223.9	)%
Other operations	36,366				36,967			(601		)	(1.6	)%
Affiliate revenue	1,005				1,030			(25		)	(2.4	)%
Operating revenue, net	833,058				759,798			73,260			9.6	%
Operating expenses
Recoverable fuel used for electric generation	257,446				205,785			(51,661		)	(25.1	)%
Recoverable power purchased for utility customers	43,365				49,186			5,821			11.8	%
FAC non-recoverable fuel and power purchased	10,195				17,981			7,786			43.3	%
Other operations	83,385				82,647			(738		)	(0.9	)%
Maintenance	55,857				51,739			(4,118		)	(8.0	)%
Depreciation	105,251				93,847			(11,404		)	(12.2	)%
Taxes other than income taxes	31,554				26,004			(5,550		)	(21.3	)%
Gain on sale of assets	—				(1		)	(1		)	(100.0	)%
Total operating expenses	587,053				527,188			(59,865		)	(11.4	)%
Operating income	$	246,005			$	232,610		$	13,395		5.8	%
Interest income	$	784			$	153		$	631		412.4	%
Allowance for other funds used during construction	$	2,880			$	4,298		$	(1,418	)	(33.0	)%
Other income	$	4,606			$	3,511		$	1,095		31.2	%
Other expense	$	3,693			$	2,698		$	(995	)	(36.9	)%
Interest charges	$	60,882			$	61,253		$	371		0.6	%
Federal and state income taxes	$	65,558			$	54,748		$	(10,810	)	(19.7	)%
Net income	$	124,142			$	121,873		$	2,269		1.9	%

Cleco Power’s net income in the first nine months of 2013 increased $2.3 million, or 1.9%, compared to the first nine months of 2012. Contributing factors include:


•	higher base revenue,


•	lower FAC non-recoverable fuel and power purchased,


•	higher other income,


•	higher interest income, and


•	lower interest charges.

These were partially offset by:


•	higher depreciation expense,


•	higher income taxes,


•	higher taxes other than income taxes,


•	higher other operations and maintenance expenses,


•	higher electric customer credits,


•	lower allowance for other funds used during construction,


•	higher other expense, and


•	lower other operations revenue.



	FOR THE NINE MONTHS ENDED SEPT. 30,
(Million kWh)	2013	2012	FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	2,839	2,834	0.2	%
Commercial	2,007	2,021	(0.7	)%
Industrial	1,723	1,710	0.8	%
Other retail	100	101	(1.0	)%
Total retail	6,669	6,666	—	%
Sales for resale	1,583	1,472	7.5	%
Unbilled	107	11	872.7	%
Total retail and wholesale customer sales	8,359	8,149	2.6	%



	FOR THE NINE MONTHS ENDED SEPT. 30,
(THOUSANDS)	2013			2012			FAVORABLE/ (UNFAVORABLE)
Electric sales
Residential	$	227,151		$	219,494		3.5	%
Commercial	141,406			136,208			3.8	%
Industrial	67,061			63,217			6.1	%
Other retail	7,860			7,436			5.7	%
Surcharge	12,496			6,801			83.7	%
Other	(4,694		)	(4,686		)	(0.2	)%
Total retail	451,280			428,470			5.3	%
Sales for resale	39,234			35,954			9.1	%
Unbilled	5,624			1,376			308.7	%
Total retail and wholesale customer sales	$	496,138		$	465,800		6.5	%

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,
				2013 CHANGE
	2013	2012	NORMAL	PRIOR YEAR		NORMAL
Heating-degree days	874	500	949	74.8	%	(7.9	)%
Cooling-degree days	2,649	2,954	2,532	(10.3	)%	4.6	%

Base

Base revenue increased $30.3 million, or 6.5%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to an annual rate adjustment associated with Cleco’s FRP, which resulted in an approximate $14.5 million increase to base revenue. Also contributing to this increase was an adjustment to customer surcredits, colder winter weather in the first quarter of 2013, and higher industrial sales, which resulted in an approximate $15.8 million increase to base revenue. For information on the anticipated effects of changes in base revenue in future periods, see “—



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

Comparison of the Three Months Ended September 30, 2013 and 2012 — 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, 2012.

Fuel Cost Recovery

Fuel cost recovery revenue billed to customers increased $45.8 million, or 18.0%, during the first nine months of 2013 compared to the first nine months in 2012 primarily due to increases in the per-unit cost of fuel used for electric generation and power purchased for utility customers. Also contributing to the increase were higher volumes of fuel used for electric generation. Partially offsetting the increase were lower 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, 2013 and 2012 — Cleco Power — Fuel Cost Recovery.”

Electric Customer Credits

Electric customer credits increased $2.3 million, or 223.9%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to the absence of the reversals of the 2012 cycle accrual and fuel audit reserves. For additional information on the accrual of 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 $0.6 million, or 1.6%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to $5.6 million of lower wholesale sales, $1.1 million from the absence of bonus lease payments, and $0.4 million of lower other miscellaneous revenue. These decreases were partially offset by $6.5 million of additional transmission revenue as a result of the implementation of transmission rates approved on February 6, 2013.

Operating Expenses

Operating expenses increased $59.9 million, or 11.4%, in the first nine months of 2013 compared to the first nine months of 2012. Recoverable fuel used for electric generation increased $51.7 million, or 25.1%, primarily due to higher per unit costs and volumes of fuel used as compared to the first nine months of 2012. Recoverable power purchased for utility customers decreased $5.8 million, or 11.8%, largely due to lower volumes of purchased power. Partially offsetting this decrease were higher per-unit costs 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. FAC non-recoverable fuel and purchased power decreased $7.8 million, or 43.3%, primarily due to lower non-recoverable wholesale power purchases. Other operations expense increased $0.7 million, or 0.9%, primarily due to higher consulting expenses, partially offset by lower customer service expenses. Maintenance expense increased $4.1 million, or 8.0%, primarily due to higher generating station outage

expenses in the first nine months of 2013. Depreciation expense increased $11.4 million, or 12.2%, primarily due to amortization of the Evangeline capacity costs and normal recurring additions to fixed assets. Taxes other than income taxes increased $5.6 million, or 21.3%, primarily due to higher property taxes.

Interest Income

Interest income increased $0.6 million, or 412.4%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to interest associated with the deferral of regulatory costs.

Allowance for Other Funds Used During Construction

Allowance for other funds used during construction decreased $1.4 million, or 33.0%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to lower AFUDC accruals resulting from the completion of miscellaneous transmission projects.

Other Income

Other income increased $1.1 million, or 31.2%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to $2.3 million of a death benefit recognized on life insurance policies. This increase was partially offset by $0.6 million of lower mutual assistance income, $0.3 million of lower royalties received, and $0.3 of miscellaneous other income.

Other Expense

Other expense increased $1.0 million, or 36.9%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to a decrease in the cash surrender value of life insurance policies of $1.9 million related to the death benefit recognized. This increase was partially offset by $0.5 million of lower mutual assistance expenses and $0.4 million of lower miscellaneous expenses.

Interest Charges

Interest charges decreased $0.4 million, or 0.6%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to $2.4 million related to an adjustment to customer surcredits due to a tax settlement, $1.8 million related to reacquired debt, $1.1 million due to pollution control bonds, and $0.9 million due to the retirement of senior notes. These amounts were partially offset by $4.4 million related to the absence of a favorable adjustment related to a tax settlement in 2012, $1.0 million related to GO Zone bonds, and $0.4 million of higher other miscellaneous interest charges.

Income Taxes

Federal and state income taxes increased $10.8 million, or 19.7%, during the first nine months of 2013 compared to the first nine months of 2012. The increase is primarily due to $5.6 million for the change in pre-tax income excluding AFUDC equity, $1.8 million for a decrease in tax credits, $1.6 million for the absence of a favorable 2012 settlement with taxing authorities, $1.1 million for a decrease in permanent tax deductions, $0.9 million for a decrease in flowthrough of tax benefits, and $0.5 million for adjustments for tax returns filed. These increases were partially offset by $0.5 million to record tax expense at the projected annual effective tax rate and $0.2 million for a decrease in the liability for uncertain tax positions.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q



Midstream
	FOR THE NINE MONTHS ENDED SEPT. 30,
							FAVORABLE/(UNFAVORABLE)
(THOUSANDS)	2013			2012			VARIANCE			CHANGE
Operating revenue
Tolling operations	$	26,483		$	21,434		$	5,049		23.6	%
Other operations	2			2			—			—	%
Operating revenue	26,485			21,436			5,049			23.6	%
Operating expenses
Fuel used for electric generation	—			304			304			100.0	%
Power purchased for utility customers	—			9			9			100.0	%
Other operations	5,439			5,684			245			4.3	%
Maintenance	8,010			9,528			1,518			15.9	%
Depreciation	4,523			4,491			(32		)	(0.7	)%
Taxes other than income taxes	1,872			1,896			24			1.3	%
Loss (gain) on sale of assets	817			(45		)	(862		)	*
Total operating expenses	20,661			21,867			1,206			5.5	%
Operating income (loss)	$	5,824		$	(431	)	$	6,255		*
Other income	$	7,250		$	19,016		$	(11,766	)	(61.9	)%
Interest charges	$	(338	)	$	244		$	582		238.5	%
Federal and state income tax expense	$	7,221		$	7,278		$	57		0.8	%
Net income	$	6,180		$	11,053		$	(4,873	)	(44.1	)%
* Not meaningful

Factors affecting Midstream during the first nine months of 2013 are described below.

Operating Revenue

Operating revenue increased $5.0 million, or 23.6%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to higher tolling revenue at Evangeline resulting from a new power purchase agreement with Cleco Power for Coughlin Units 6 and 7 that began in May 2012 as compared to the power purchase agreement with Cleco Power for Coughlin Unit 6 in effect from January through April 2012. Also contributing to this increase was the absence of availability penalties from Coughlin Unit 7 in June 2012.

Operating Expenses

Operating expenses decreased $1.2 million, or 5.5%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to lower maintenance expenses at Evangeline due to lower turbine and routine maintenance expense. Partially offsetting this decrease was a loss in 2013 on the disposal of assets at Evangeline from higher removal and parts retirement expense.

Other Income

Other income decreased $11.8 million, or 61.9%, during the first nine months of 2013 compared to the first nine months of 2012 largely due to lower contractual expirations of underlying indemnifications resulting from the disposition of Acadia Units 1 and 2.

Interest Charges

Interest charges decreased $0.6 million, or 238.5%, during the first nine months of 2013 compared to the first nine months of 2012 primarily related to $0.5 million for a change in uncertain tax positions and $0.1 million of lower miscellaneous interest charges.

Income Taxes

Federal and state income taxes decreased $0.1 million, or 0.8%, during the first nine months of 2013 compared to the first nine months of 2012 primarily due to $1.9 million for the change in pre-tax income and $0.1 million for adjustments for tax returns filed, partially offset by $1.9 for the increase in the liability for uncertain tax positions.

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, 2013.



	SENIOR UNSECURED DEBT		CORPORATE CREDIT
	MOODY’S	S&P	S&P
Cleco Corporation	Baa3	N/A	BBB+
Cleco Power	Baa2	BBB+	N/A

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.

On July 26, 2013, S&P upgraded Cleco Corporation’s corporate credit rating and Cleco Power’s unsecured credit rating to BBB+ from BBB. At that time, S&P revised the outlook from positive to stable. Cleco Corporation and Cleco Power pay fees and interest under their bank credit agreements based on the highest rating held. All-in interest rates under the facilities are 0.25% lower due to the ratings upgrade and savings are dependent upon the level of borrowings. On August 16, 2013, Moody’s changed its outlook to positive from stable for both Cleco Corporation and Cleco Power. If Cleco Corporation or Cleco Power’s credit rating were to be downgraded by Moody’s or S&P, Cleco Corporation and/or Cleco Power would be required to pay additional fees and



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

incur higher interest rates for borrowings 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 S&P, 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.

In June 2013, the LPSC approved Cleco Power’s application to join MISO and to find that transferring control of certain transmission assets to MISO was in the public interest, to create an accounting order deferring costs related to Cleco Power’s transition into the MISO market, and to expedite treatment. MISO operates a fully functioning RTO market. The vast majority of the transactions are settled through the day-ahead market; however, MISO also operates a real-time energy market to address the deviations between day-ahead and real-time schedules. Due to the timing of the settlement of such schedules, Cleco Power will be required to provide credit support for MISO and this may cause the amount of requested credit support to increase or decrease. At this time there are no initial credit requirements.

Global and U.S. Economic Environment

The current economic environment and uncertainty may have an impact on Cleco’s business and financial condition. Future actions or inactions of the U.S. federal government, including a failure to increase the government debt limit or another shutdown of the federal government, could increase the actual or perceived risk that the U.S. may not ultimately pay its obligations when due and may disrupt financial markets, including capital markets. 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 in the past 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

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.”

Cash Generation and Cash Requirements

Restricted Cash and Cash Equivalents



(THOUSANDS)	AT SEPT. 30, 2013		AT DEC. 31, 2012
Diversified Lands’ mitigation escrow	$	97	$	97
Cleco Katrina/Rita’s storm recovery bonds	3,359		8,781
Cleco Power’s future storm restoration costs	4,944		5,343
Cleco Power’s building renovation escrow	71		—
Total restricted cash and cash equivalents	$	8,471	$	14,221

Cleco Katrina/Rita has the right to bill and collect storm restoration costs from Cleco Power’s customers. As cash is collected, it is restricted for payment of administration fees, interest, and principal on storm recovery bonds. During the nine months ended September 30, 2013, Cleco Katrina/Rita collected $14.9 million net of administration fees. In March and September 2013, Cleco Katrina/Rita used $7.1 million and $6.8 million, respectively for scheduled storm recovery bond principal payments and $3.3 million and $3.1 million, respectively for related interest.

Debt

Cleco Consolidated

At September 30, 2013 and December 31, 2012, Cleco had no short-term debt outstanding.



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q

September 2013, and a $1.6 million decrease in capital lease obligations. These decreases were partially offset by $35.0 million outstanding on a bank term loan entered into in March 2013, the issuance of $50.0 million 2008 Series A GO Zone bonds and $50.0 million 2008 Series B GO Zone bonds in May 2013, and debt discount amortizations of $0.3 million.

Cash and cash equivalents available at September 30, 2013, were $46.8 million combined with $550.0 million credit facility capacity ($250.0 million from Cleco Corporation and $300.0 million from Cleco Power) for total liquidity of $596.8 million. Cash and cash equivalents available at September 30, 2013, increased $15.8 million when compared to cash and cash equivalents available at December 31, 2012. This increase was primarily due to an increase in customer receipts and the receipt of tax refunds. Partially offsetting this increase was higher vendor payments, the payment of common stock dividends, interest payments, contributions to the pension plan, credit facility draw repayments, routine working capital fluctuations, and payment of property taxes.

At September 30, 2013, 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, 2013 and December 31, 2012, Cleco had a working capital surplus of $132.8 million and $152.7 million, respectively. The $19.9 million decrease in working capital is primarily due to:


•	a $152.4 million net increase in current tax liabilities and uncertain tax positions and related interest charges expected to be settled in the next 12 months and


•	an $11.9 million increase in accrued interest.

These decreases in working capital were partially offset by:


•	a $74.0 million decrease in long-term debt due within one year which reflects the refinancing of long-term debt,


•	a $17.1 million increase in customer accounts receivable,


•	a $15.9 million decrease in accounts payable primarily due to payments of ad valorem tax, employee incentives and fuel that were accrued at year end,


•	a $15.8 million increase in unrestricted cash and cash equivalents as discussed above, and


•	an $8.3 million decrease in regulatory liabilities due to the return of customer owed carrying costs related to the construction of Madison Unit 3.

Cleco Corporation (Holding Company Level)

Cleco Corporation had no short-term debt outstanding at September 30, 2013 or December 31, 2012.

At September 30, 2013, Cleco Corporation had no draws outstanding under its $250.0 million credit facility compared to $25.0 million outstanding at December 31, 2012. 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, 2013, were $4.0 million, combined with $250.0 million credit facility capacity for total liquidity of $254.0 million. Cash and cash equivalents available at September 30, 2013, decreased $3.4 million when compared to cash and cash equivalents available at December 31, 2012, primarily due to higher vendor payments, the payment of common stock dividends, credit facility draw repayments, routine working capital fluctuations, and payment of property taxes. Partially offsetting this decrease was a tax refund.

Cleco Power

At September 30, 2013 and December 31, 2012, Cleco Power had no short-term debt outstanding.

At September 30, 2013, Cleco Power’s long-term debt outstanding was $1.31 billion, of which $17.1 million was due within one year. The long-term debt due within one year at September 30, 2013, represents $14.9 million principal payments for the Cleco Katrina/Rita storm recovery bonds and $2.2 million of capital lease payments.

For Cleco Power, long-term debt decreased $15.3 million from December 31, 2012, primarily due to a $75.0 million repayment of senior notes, $60.0 million solid waste disposal bonds reacquired in March 2013, $14.0 million scheduled Cleco Katrina/Rita storm recovery bond principal payments made in March and September 2013, and a $1.6 million decrease in capital lease obligations. These decreases were partially offset by $35.0 million outstanding on a bank term loan entered into in March 2013, the issuance of $50.0 million 2008 Series A GO Zone bonds and $50.0 million 2008 Series B GO Zone bonds in May 2013, and debt discount amortizations of $0.3 million.

At September 30, 2013 and December 31, 2012, there were no borrowings outstanding under Cleco Power’s $300.0 million credit facility. This facility provides for working capital and other needs.

Cash and cash equivalents available at September 30, 2013, were $42.6 million, combined with $300.0 million facility capacity for total liquidity of $342.6 million. Cash and cash equivalents increased $19.2 million, when compared to cash and cash equivalents at December 31, 2012. This increase is primarily due to an increase in customer receipts. Partially offsetting this increase was higher vendor payments, interest payments, contributions to the pension plan, payment of property taxes, and routine working capital fluctuations.

At September 30, 2013 and December 31, 2012, Cleco Power had a working capital surplus of $118.9 million and $96.3 million, respectively. The $22.6 million increase in working capital is primarily due to:


•	a $74.0 million decrease in long-term debt due within one year which reflects the refinancing of long-term debt,


•	a $19.2 million increase in unrestricted cash and cash equivalents, as discussed above,



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q


•	a $17.1 million increase in customer accounts receivable,


•	an $8.3 million decrease in regulatory liabilities due to the return of customer owed carrying costs related to the construction of Madison Unit 3, and


•	a $12.3 million decrease in accounts payable primarily due to payments of ad valorem tax, employee incentive and fuel that were accrued at year end.

These increases in working capital were partially offset by:


•	a $99.4 million net increase in current tax liabilities and uncertain tax positions and related interest charges expected to be settled in the next 12 months and


•	an $11.8 million increase in accrued interest.

On May 3, 2013, Cleco Power remarketed $50.0 million of its 2008 Series A GO Zone bonds which had previously been purchased by Cleco Power and were being held as treasury bonds. The interest rate at September 30, 2013, was 0.94% which is based on 65% of one month LIBOR, plus 0.82%. The rate resets monthly. The 2008 Series A GO Zone bonds will be subject to remarketing on May 3, 2015. Of the $50.0 million bonds, $25.0 million of the proceeds were used to fund the partial repayment of the $60.0 million solid waste disposal bonds described above and $25.0 million of the proceeds were used to partially fund the maturity of Cleco Power’s $75.0 million 5.375% senior notes on May 1, 2013.

Credit Facilities

At September 30, 2013, Cleco Corporation had no borrowings outstanding under its existing credit facility. Cleco Corporation’s credit facility agreement has a maximum capacity of $250.0 million. The borrowing costs under the facility are equal to one-month LIBOR plus 1.275% or ABR, plus facility fees of 0.225%. 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 under the pricing levels of its credit facility.

At September 30, 2013, Cleco Power had no borrowings outstanding under its existing credit facility. Cleco Power’s credit facility agreement has a maximum capacity of $300.0 million. The borrowing costs are LIBOR plus 1.075% or ABR, plus facility fees of 0.175%. 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 under the pricing levels of its credit facility.

At September 30, 2013, 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.

On October 16, 2013, Cleco Corporation and Cleco Power entered into new, amended and restated credit facilities with maturity dates of October 16, 2018. The new facilities replace the previous facilities, which were to mature on October 7, 2016. The new facilities are comprised of the same ten banks, plus one additional bank. The new facilities are priced the same as the old facilities and are for the same amounts.

Midstream

Midstream had no debt outstanding at September 30, 2013 or December 31, 2012.

Cleco Consolidated Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $289.7 million during the first nine months of 2013, compared to $224.6 million during the first nine months of 2012. Cash provided by operating activities during the first nine months of 2013 increased $65.1 million from the first nine months of 2012 primarily due to the following items:


•	higher income tax refunds of $47.2 million,


•	lower refund of Madison Unit 3 carrying costs of $23.8 million due to extinguishment of the liability,


•	lower expenditures for fuel inventories and related transportation of $10.9 million, primarily petroleum coke and lignite,



CLECO CORPORATION
CLECO POWER		2013 3RD QUARTER FORM 10-Q


•	lower storm expenditures of $7.1 million,


•	lower payroll of $5.1 million, and


•	lower vendor payments of $4.8 million.

These increases were partially offset by higher pension plan contributions of $34.0 million.

Net Investing Cash Flow

Net cash used in investing activities was $164.8 million during the first nine months of 2013, compared to $149.2 million during the first nine months of 2012. Net cash used in investing activities during the first nine months of 2013 was higher than the first nine months of 2012 primarily due to the following items:


•	lower return of investment in the NMTC Fund of $36.7 million,


•	lower property, plant, and equipment grants received of $14.3 million, and


•	lower transfers of cash from restricted accounts of $13.3 million.

These increases were partially offset by lower additions to property, plant, and equipment, net of AFUDC, of $44.2 million.

Net Financing Cash Flow

Net cash used in financing activities was $109.1 million during the first nine months of 2013 compared to $100.6 million during the first nine months of 2012. Net cash used in financing activities during the first nine months of 2013 was higher than the first nine months of 2012 primarily due to the following items:


•	higher repayments on the revolving credit facility of $213.0 million,


•	the repurchase of long-term debt of $60.0 million, and


•	higher retirement of long-term debt of $39.6 million.

These increases were partially offset by:


•	draws on the revolving credit facility of $198.0 million and


•	higher issuances of long-term debt of $110.0 million.

Cleco Power Cash Flows

Net Operating Cash Flow

Net cash provided by operating activities was $232.0 million during the first nine months of 2013, compared to $205.5 million during the first nine months of 2012. Cash provided by operating activities during the first nine months of 2013 increased $26.5 million from the first nine months of 2012 primarily due to the following items:


•	lower refund of Madison Unit 3 carrying costs of $23.8 million due to extinguishment of the liability,


•	lower expenditures for fuel inventories and related transportation of $10.9 million, primarily petroleum coke and lignite,


•	lower storm expenditures of $7.1 million,


•	lower vendor payments of $4.6 million, and


•	lower payroll of $3.8 million.

These increases were partially offset by higher pension plan contributions of $34.0 million.

Net Investing Cash Flow

Net cash used in investing activities was $118.2 million during the first nine months of 2013, compared to $138.3 million during the first nine months of 2012. Net cash used in investing activities during the first nine months of 2013 was lower than the first nine months of 2012 primarily due to lower additions to property, plant, and equipment, net of AFUDC, of $44.9 million.

This decrease was partially offset by:


•	lower property, plant, and equipment grants received of $14.3 million and


•	lower transfers of cash from restricted accounts of $13.4 million.

Net Financing Cash Flow

Net cash used in financing activities was $94.6 million during the first nine months of 2013 compared to $84.1 million during the first nine months of 2012. Net cash used in financing activities during the first nine months of 2013 was higher than the first nine months of 2012 primarily due to the following items:


•	repayments on the revolving credit facility of $160.0 million,


•	the repurchase of long-term debt of $60.0 million,


•	higher retirement of long-term debt of $39.6 million, and


•	higher distributions to Cleco Corporation of $17.0 million.

These increases were partially offset by:


•	draws on the revolving credit facility of $160.0 million and


•	higher issuances of long-term debt of $110.0 million.

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 Condensed 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, 2012.

Off-Balance Sheet Commitments and Disclosures about Guarantees



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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 in April 2012. In August 2012, Cleco Power filed a written report to the LPSC regarding co-firing biomass fuel in Madison Unit 3. At its August 21, 2013 meeting, the LPSC decided Cleco met their requirements relating to the renewable energy pilot program. 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, 2012.

RFP for Contractual Resources Beginning in May 2012

In September 2011, Cleco Power issued a draft RFP for resources and conducted a technical and 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 with Evangeline providing 730 MW of capacity and energy 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, environmental regulations, and the expiration of the Evangeline power

purchase agreement discussed above. 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. In October 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. In December 2012, Cleco Power and Evangeline executed definitive agreements to transfer ownership and control of Coughlin from Evangeline to Cleco Power. Cleco Power's application seeking regulatory approval is listed in the LPSC's Official Bulletin, dated April 12, 2013. In May 2013, Cleco Power filed its application with FERC seeking authorization to acquire Coughlin, and subsequently received authorization from FERC on August 26, 2013. The transaction is expected to close on or before April 30, 2014, following regulatory approval by the LPSC.

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.

For more information on MATS, see “— Results of Operations — Cleco Power — MATS.” 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, 2012.

Retail Rates of Cleco Power

For information concerning Cleco Power’s current FRP, the pending request for extension of the FRP, 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.”

In August 2009, the LPSC opened a docket to study the promotion of energy efficiency by jurisdictional electric and natural gas utilities. On September 20, 2013, the commission issued their General Order adopting amended energy efficiency rules, which were previously rescinded by the LPSC’s order on March 28, 2013. On September 30, 2013, Cleco Power filed its formal intent to participate in the Phase I - Quick Start Process as defined in the LPSC’s Order. Phase I is intended to expedite the implementation of energy efficiency programs by developing detailed policies designed to implement cost-effective options. The new rules are not expected to have a material impact on the results of operations, financial condition, or cash flows of Cleco Power.



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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, 2012.

Transmission Rates of Cleco Power

Transmission Service

On March 29, 2012, Cleco Power filed a request with FERC for revisions to its 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 permit recovery of Cleco Power’s FERC-jurisdictional investments in transmission and other assets placed in service since the existing rates were established. In May 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 were suspended for the maximum five-month statutory period and were effective November 1, 2012, subject to refund. On February 6, 2013, Cleco Power received notification that FERC had approved its settlement agreement filed on December 21, 2012. This settlement agreement allows for a return on equity of 10.5%, with an equity ratio of 53%. In accordance with the settlement, Cleco Power shall discount the charges produced by the formula rate by 10% until the earlier of December 31, 2014, or the date upon which Cleco commences operations under the MISO tariff, currently anticipated to be December 2013.

For more information on the transmission rates of Cleco Power, 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, 2012 and “— Financial Condition — Regulatory and Other Matters — Market Restructuring — Wholesale Electric Markets.”

Integrated Resource Plan (IRP)

In accordance with the General Order in LPSC Docket No. R-30021, Cleco Power filed a request with the commission to initiate an IRP process on October 21, 2013. The IRP process includes conducting stakeholder meetings and receiving feedback from stakeholders. The schedule outlined in the General Order calls for Cleco Power to file a draft IRP in October 2014, and a final report in May 2015.

Market Restructuring

Wholesale Electric Markets

Regional Transmission Organization

On December 6, 2012, Cleco Power filed an application with the LPSC indicating Cleco’s intent to join MISO, asking the commission to find that transferring control of certain transmission assets to MISO is in the public interest, to create an accounting order deferring costs related to Cleco Power’s transition into the MISO market, and to expedite treatment. On June 26, 2013, the LPSC unanimously approved Cleco Power’s

change of control request. On June 18, 2013, Cleco Power filed a related application with the LPSC requesting approval of Cleco Power’s proposed MISO integration, implementation, and ratemaking plans. Discovery related to this integration, implementation, and ratemaking phase is still ongoing with a vote anticipated from the LPSC in mid-November 2013. Cleco Power anticipates joining the MISO RTO in December 2013.

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, 2012.

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, 2012.

Lignite Deferral

At September 30, 2013 and December 31, 2012, Cleco Power had $14.7 million and $16.6 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, 2012.

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 $72.4 million, with the DOE grant providing $20.0 million toward the project and Cleco Power providing the remaining $52.4 million. The grant program is a part of the American Recovery and Reinvestment Act of 2009. Advanced metering technology allows Cleco Power to better manage its electric system and provides improved service to customers through the meter’s communicating capabilities. At September 30, 2013, Cleco Power had incurred $69.7 million in project costs, of which $20.0 million has been reimbursed by the DOE. The installation of the advanced meters was substantially completed in May 2013, with the project to be fully functional by the fourth 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, 2012.

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



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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. Cleco Power has registered on the International Swaps and Derivatives Association (ISDA) website and submitted the required adherence letters and questionnaires pertinent to the ISDA August 2012 Dodd-Frank Act Protocol and the ISDA March 2013 Dodd-Frank Act Protocol. Management continues to review the final 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 July 10, 2013, the Town of Cottonport unanimously voted to approve a new franchise agreement with Cleco Power with an effective date of July 16, 2013. The franchise agreement is for 30 years until July 2043. Approximately 1,085 Cleco Power customers are located in Cottonport.

On July 15, 2013, the Village of Moreauville unanimously voted to approve a new franchise agreement with Cleco Power with an effective date of July 19, 2013. The franchise agreement is for 30 years until July 2043. Approximately 573 Cleco Power customers are located in Moreauville.

On August 8, 2013, the City of Mandeville unanimously voted to approve a new franchise agreement with Cleco Power with an effective date of August 9, 2013. The franchise agreement is for 30 years until August 2043. Approximately 7,001 Cleco Power customers are located in Mandeville.

On August 12, 2013, the Town of Oberlin unanimously voted to approve a new franchise agreement with Cleco Power with an effective date of August 26, 2013. The franchise agreement is for 30 years until August 2043. Approximately 693 Cleco Power customers are located in Oberlin.

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, 2012.

Other Franchise Matters

For information regarding other franchise matters, 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.

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, 2012.

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, 2013 and September 30, 2012. The following 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 2013 and the first nine months of 2012. 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, 2012.

For an explanation of material changes in the amount of revenue and expense items of Cleco Power between the third quarter of 2013 and the third quarter of 2012, see “— Results of Operations — Comparison of the Three Months Ended September 30, 2013 and 2012 — 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 2013 and the first nine months of 2012, see “— Results of Operations — Comparison of the Nine Months Ended September 30, 2013 and 2012 — 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

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 FAC and reflected on customers’ bills as a component of the FAC.

Cleco’s exposure to market risk, as discussed below, represents an estimate of possible changes in the fair value or future earnings that would occur, assuming possible future movements in the interest rates and commodity prices of power 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 past years have limited the availability and have increased the costs of capital for many companies. Future actions or inactions of the U.S. federal government, including a failure to increase the government debt limit or another shutdown of the federal government, could increase the actual or perceived risk that the U.S. may not ultimately pay its obligations when due and may disrupt financial markets, including capital markets. 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 or S&P, 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 S&P 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, 2013, Cleco had no short-term variable rate debt and $85.0 million in long-term variable-rate debt.

At September 30, 2013, Cleco Corporation had no borrowings outstanding under its $250.0 million credit facility.

In November 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 had a spot 30-year all-in swap rate of 3.05%, notional amount of $50.0 million, with the pricing date of May 14, 2013, or the issuance of the notes, whichever was earlier. The forward starting interest rate swap met the criteria of a cash flow hedge under the authoritative guidance as it relates to derivatives and hedging and was carried on the balance sheet at its fair value.

During the first quarter of 2013, Cleco determined that the forward starting interest rate swap ceased to be highly effective in offsetting changes in the cash flows of the forecasted coupon payments and discontinued hedge accounting prospectively. In May 2013, upon pricing of the 2008 Series B GO Zone bonds, Cleco Power settled the forward starting interest rate swap at a loss of $3.3 million. Of this amount, Cleco Power deferred $2.9 million as a regulatory asset and recognized $0.4 million in other comprehensive income. In May 2013, Cleco Power began amortizing these losses over the 25-year term of the related debt.

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 Value-at-Risk, current market conditions, and concentration of energy market positions.

Cleco Power procures fuel for generation and purchases power to meet the power demands of customers. Cleco Power may enter into positions to mitigate the volatility in customer fuel costs, as encouraged by various LPSC orders. These positions 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 and a component



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of the energy risk management assets or liabilities. When these positions close, actual gains or losses will be included in the FAC and reflected in customers’ bills as a component of the fuel cost adjustment. There were no open positions at September 30, 2013 or December 31, 2012.

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-term variable-rate debt and $85.0 million in long-term variable-rate debt as of September 30, 2013.

On March 20, 2013, Cleco Power entered into a bank term loan agreement in the amount of $60.0 million. At September 30, 2013, Cleco Power had $35.0 million outstanding under the bank term loan. The interest rate under

the agreement at September 30, 2013, was 0.93%. The rate resets monthly at one month LIBOR, plus 0.75%. Each 1% increase in the interest rate applicable to such debt would have resulted in a decrease in Cleco Power’s pre-tax earnings of $0.4 million.

On May 3, 2013, Cleco Power remarketed $50.0 million of its 2008 Series A GO Zone bonds which had previously been purchased by Cleco Power and were being held as treasury bonds. The interest rate at September 30, 2013, was 0.94% which is based on 65% of one month LIBOR, plus 0.82%. The rate resets monthly. The 2008 Series A GO Zone bonds will be subject to remarketing on May 3, 2015. Each 1% increase in the interest rate applicable to such debt would have resulted in a decrease in Cleco Power’s pre-tax earnings of $0.5 million.

At September 30, 2013, Cleco Power had no borrowings outstanding under its $300.0 million credit facility.

Please refer to “— Commodity Price Risks” for a discussion of controls, transactions, Value-at-Risk, 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, 2013, evaluations were performed under the supervision and with the participation of Cleco Corporation and Cleco Power (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, 2013, that has materially affected, or is reasonably likely to materially affect, the Registrants’ internal control over financial reporting.



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PART II — OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

CLECO

For information on legal proceedings affecting Cleco, see Part

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

Financial Statements — Note 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, 2012 (the “2012 Annual Report on Form 10-K”). For risks that could affect actual results and cause results to differ materially from those expressed in any forward-looking statements made by, or on behalf of, the Registrants, see the risk factors disclosed under “Risk Factors” in Item 1A of the 2012 Annual Report on Form 10-K.

Reliability and Infrastructure Protection Standards Compliance

Cleco is subject to mandatory reliability and critical infrastructure protection standards. Fines and civil penalties are imposed on those who fail to comply with these standards.

NERC serves as the ERO with authority to establish and enforce mandatory reliability and infrastructure protection standards, subject to FERC approval, for users of the nation’s transmission system. FERC enforces compliance with these standards. New standards are being developed and existing standards are continuously being modified.

As these standards continue to be adopted and modified, they may impose additional compliance requirements on Cleco Power and Midstream operations, which may result in an increase in capital expenditures and operating expenses. Failure to comply with these standards can result in the imposition of material fines and civil penalties.

In December 2012, the Southwest Power Pool Regional Entity notified Cleco that an audit would be conducted to determine Cleco’s compliance with the NERC Critical Infrastructure Protection cybersecurity standard requirements. The audit was conducted in March 2013. Cleco submitted mitigation plans and evidence of remedial efforts in connection with the SPP’s initial findings from the audit. Cleco and the SPP agreed to a financial settlement totaling less than $0.1 million. The next NERC Reliability audit is scheduled to begin in November 2013. Management is unable to predict the outcome of the future audit or whether it will have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.

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 25, 2013, the Board of Directors of Cleco Corporation amended Cleco Corporation’s Bylaws to eliminate the staggered board structure. Prior to the amendment, the Bylaws required the classification of the Board of Directors into three classes of, as near as possible, equal size. The amendment requires the Board of Directors to be elected by the shareholders annually. Section 1(d)(3) of Article III of the Bylaws also was deleted. Pursuant to the Bylaws, the Board of

Directors’ terms cannot be shortened. Therefore, the declassified board structure will be phased in, and all Directors will be elected on an annual basis beginning in 2017. Both amendments are effective October 25, 2014, pursuant to Section 1 of Article XIV of the Bylaws, which provides for a delayed effective date for amendments to certain Bylaws provisions. The revised Bylaws are filed as Exhibit 3.1 to this Combined Quarterly Report on Form 10-Q.



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ITEM 6. EXHIBITS
CLECO CORPORATION
3.1	Bylaws of Cleco Corporation, revised effective October 25, 2014
10.1	Amended and Restated Credit Agreement dated as of October 16, 2013 among Cleco Corporation, various financial institutions, and JPMorgan Chase Bank, N.A., as administrative agent (incorporated by reference to Exhibit 10.1 of Cleco Corporation Form 8-K (file no. 001-15759), filed with the SEC on October 17, 2013)
12(a)	Computation of Ratios of Earnings to Fixed Charges for the three-, nine-, and twelve-month periods ended September 30, 2013, 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
10.2	Amended and Restated Credit Agreement dated as of October 16, 2013 among Cleco Power LLC, various financial institutions, and JPMorgan Chase Bank, N.A., as administrative agent (incorporated by reference to Exhibit 10.2 of Cleco Corporation Form 8-K (file no. 001-05663), filed with the SEC on October 17, 2013)
12(b)	Computation of Ratios of Earnings to Fixed Charges for the three-, nine-, and twelve-month periods ended September 30, 2013, 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



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CLECO POWER		2013 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, 2013

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, 2013

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Cleco Power 10-Q2013 Q3 Quarterly report

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