0001089819-11-000022.txt : 20110504 0001089819-11-000022.hdr.sgml : 20110504 20110504171450 ACCESSION NUMBER: 0001089819-11-000022 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 24 CONFORMED PERIOD OF REPORT: 20110331 FILED AS OF DATE: 20110504 DATE AS OF CHANGE: 20110504 FILER: COMPANY DATA: COMPANY CONFORMED NAME: CLECO POWER LLC CENTRAL INDEX KEY: 0000018672 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC SERVICES [4911] IRS NUMBER: 720244480 STATE OF INCORPORATION: LA FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-05663 FILM NUMBER: 11811358 BUSINESS ADDRESS: STREET 1: 2030 DONAHUE FERRY ROAD CITY: PINEVILLE STATE: LA ZIP: 71360-5226 BUSINESS PHONE: 3184847400 MAIL ADDRESS: STREET 1: 2030 DONAHUE FERRY ROAD CITY: PINEVILLE STATE: LA ZIP: 71360-5226 FORMER COMPANY: FORMER CONFORMED NAME: CLECO UTILITY GROUP INC DATE OF NAME CHANGE: 19990708 FORMER COMPANY: FORMER CONFORMED NAME: CENTRAL LOUISIANA ELECTRIC CO INC DATE OF NAME CHANGE: 19920703 FILER: COMPANY DATA: COMPANY CONFORMED NAME: CLECO CORP CENTRAL INDEX KEY: 0001089819 STANDARD INDUSTRIAL CLASSIFICATION: ELECTRIC SERVICES [4911] IRS NUMBER: 721445282 STATE OF INCORPORATION: LA FISCAL YEAR END: 1231 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-15759 FILM NUMBER: 11811357 BUSINESS ADDRESS: STREET 1: 2030 DONAHUE FERRY ROAD CITY: PINEVILLE STATE: LA ZIP: 71360-5226 BUSINESS PHONE: 3184847400 MAIL ADDRESS: STREET 1: PO BOX 5000 CITY: PINEVILLE STATE: LA ZIP: 71361-5000 FORMER COMPANY: FORMER CONFORMED NAME: CLECO HOLDING CORP DATE OF NAME CHANGE: 19990630 10-Q 1 clecocorp10q_033111.htm CLECO CORPORATION AND CLECO POWER LLC 2011 1ST QUARTER SEC FORM 10-Q clecocorp10q_033111.htm


 
UNITED STATES SECURITIES AND EXCHANGE COMMISSION
 
Washington, D.C.  20549
__________________

FORM 10-Q

 
x  QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the quarterly period ended March 31, 2011
 
Or
 
¨  TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
__________________

 
Commission file number 1-15759
CLECO CORPORATION
(Exact name of registrant as specified in its charter)
   
Louisiana
(State or other jurisdiction of incorporation or organization)
 
72-1445282
(I.R.S. Employer Identification No.)
   
2030 Donahue Ferry Road, Pineville, Louisiana
(Address of principal executive offices)
 
71360-5226
(Zip Code)
   
Registrant’s telephone number, including area code:  (318) 484-7400
 
__________________

 
Commission file number 1-05663
CLECO POWER LLC
(Exact name of registrant as specified in its charter)
   
Louisiana
(State or other jurisdiction of incorporation or organization)
 
72-0244480
(I.R.S. Employer Identification No.)
   
2030 Donahue Ferry Road, Pineville, Louisiana
(Address of principal executive offices)
 
71360-5226
(Zip Code)
   
Registrant’s telephone number, including area code:  (318) 484-7400
 
 
Indicate by check mark whether the Registrants: (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the Registrants were required to file such reports) and (2) have been subject to such filing requirements for the past 90 days.  
Yes x    No ¨
 
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 ¨    No ¨
 
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 ¨                  Non-accelerated filer ¨  (Do not check if a smaller reporting company)            Smaller reporting company ¨
 
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 ¨           Accelerated filer ¨                  Non-accelerated filer x  (Do not check if a smaller reporting company)            Smaller reporting company ¨
 
Indicate by check mark whether the Registrants are shell companies (as defined in Rule 12b-2 of the Exchange Act)  Yes¨    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 April 29, 2011
 
       
Cleco Corporation
Common Stock, $1.00 Par Value
  60,979,231  

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       
2011 1ST QUARTER FORM 10-Q
 
 
This Combined Quarterly Report on Form 10-Q is separately filed by Cleco Corporation and Cleco Power.  Information in this filing relating to Cleco Power is filed by Cleco Corporation and separately by Cleco Power on its own behalf.  Cleco Power makes no representation as to information relating to Cleco Corporation (except as it may relate to Cleco Power) or any other affiliate or subsidiary of Cleco Corporation.
This report should be read in its entirety as it pertains to each respective Registrant.  The Notes to the Unaudited Condensed Consolidated Financial Statements are combined.
 
TABLE OF CONTENTS
 
PAGE
GLOSSARY OF TERMS
3
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS
5
     
PART I
Financial Information
 
ITEM 1.
Cleco Corporation — Condensed Consolidated Financial Statements
7
 
Cleco Power — Condensed Consolidated Financial Statements
13
 
Notes to the Unaudited Condensed Consolidated Financial Statements
18
ITEM 2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
36
ITEM 3.
Quantitative and Qualitative Disclosures about Market Risk
49
ITEM 4.
Controls and Procedures
51
     
PART II
Other Information
 
ITEM 1.
Legal Proceedings
52
ITEM 1A.
Risk Factors
52
ITEM 5.
Other Information
52
ITEM 6.
Exhibits
53
 
Signatures
54


 
 
2

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
GLOSSARY OF TERMS

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

ABBREVIATION OR ACRONYM
DEFINITION
401(k) Plan
Cleco Power 401(k) Savings and Investment Plan
ABR
Alternate Base Rate
Acadia
Acadia Power Partners, LLC, which is 100% owned by Cajun and consisted of Acadia Unit 2 from February 23, 2010 to April 29, 2011.  Prior to February 23, 2010, Acadia was 50% owned by APH and 50% owned by Cajun and consisted of Acadia Unit 1 and Acadia Unit 2.  
Acadia Unit 1
Cleco Power’s 580-MW unit, combined cycle, natural gas-fired power plant located at the Acadia Power Station near Eunice, Louisiana
Acadia Unit 2
Entergy Louisiana’s 580-MW unit, combined cycle, natural gas-fired power plant located at the Acadia Power Station near Eunice, Louisiana.  Prior to April 29, 2011, Acadia Unit 2 was owned by Acadia.
Acadiana Load Pocket
An area in south central Louisiana that has experienced transmission constraints caused by local load and lack of generation.  Transmission within the Acadiana Load Pocket is owned by several entities, including Cleco Power.
AFUDC
Allowance for Funds Used During Construction
Amended EPC Contract
Amended and Restated EPC Contract between Cleco Power and Shaw, executed on May 12, 2006, for engineering, procurement, and construction of Madison Unit 3, as amended by Amendment No. 1 thereto effective March 9, 2007, Amendment No. 2 thereto dated as of July 2, 2008, Amendment No. 3 thereto dated as of July 22, 2009, and Amendment No. 4 thereto dated October 19, 2009.
Amended Lignite Mining Agreement
Amended and restated lignite mining agreement effective December 29, 2009
AMI
Advanced Metering Infrastructure
APH
Acadia Power Holdings LLC, a wholly owned subsidiary of Midstream
Attala
Attala Transmission LLC, a wholly owned subsidiary of Cleco Corporation
Cajun
Cajun Gas Energy L.L.C., 50% owned by APH and 50% owned by third parties.  Prior to February 23, 2010, Cajun was 100% owned by third parties.
Cleco Innovations LLC
A wholly owned subsidiary of Cleco Corporation
Cleco Katrina/Rita
Cleco Katrina/Rita Hurricane Recovery Funding LLC, a wholly owned subsidiary of Cleco Power
Coughlin
Coughlin Power Station, a combined-cycle, natural gas-fired power plant located in Evangeline Parish, Louisiana.  On June 11, 2010, Evangeline Power Station was renamed Coughlin Power Station.
DHLC
Dolet Hills Lignite Company, LLC, a wholly owned subsidiary of SWEPCO
Diversified Lands
Diversified Lands LLC, a wholly owned subsidiary of Cleco Innovations LLC
DOE
United States Department of Energy
Entergy Gulf States
Entergy Gulf States Louisiana, L.L.C., formerly Entergy Gulf States, Inc.
Entergy Louisiana
Entergy Louisiana, LLC
Entergy Mississippi
Entergy Mississippi, Inc.
Entergy Services
Entergy Services, Inc., as agent for Entergy Louisiana and Entergy Gulf States
EPA
United States Environmental Protection Agency
EPC
Engineering, Procurement, and Construction
ESPP
Cleco Corporation Employee Stock Purchase Plan
Evangeline
Cleco Evangeline LLC, a wholly owned subsidiary of Midstream, and its combined cycle, natural gas-fired power plant located in Evangeline Parish, Louisiana.  On June 11, 2010, the power plant was renamed Coughlin Power Station.
Evangeline 2010 Tolling Agreement
Capacity Sale and Tolling Agreement between Evangeline and JPMVEC, which was executed in February 2010
Evangeline Restructuring Agreement
Purchase, Sale and Restructuring Agreement entered into on February 22, 2010, by Evangeline and JPMVEC
Evangeline Tolling Agreement
Capacity Sale and Tolling Agreement between Evangeline and BE Louisiana LLC (as successor to Williams Power Company, Inc.) which was set to expire in 2020 and was terminated in February 2010.  In September 2008, BE Louisiana LLC was merged into JPMVEC.
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)
GW
Gigawatt(s) as applicable
ICT
Independent Coordinator of Transmission
Interconnection Agreement
One of two Interconnection Agreement and Real Estate Agreements, one between Attala and Entergy Mississippi, and the other between Perryville and Entergy Louisiana
IRP
Integrated Resource Planning
IRS
Internal Revenue Service
JPMVEC
J.P. Morgan Ventures Energy Corporation.  In September 2008, BE Louisiana LLC was merged into JPMVEC.
kWh
Kilowatt-hour(s) as applicable
LDEQ
Louisiana Department of Environmental Quality
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

 
 
3

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
ABBREVIATION OR ACRONYM
DEFINITION
Madison Unit 3
A 600-MW solid-fuel generating unit at Cleco Power’s plant site in Boyce, Louisiana that commenced commercial operation on February 12, 2010.  Prior to June 11, 2010, Madison Unit 3 was known as Rodemacher Unit 3.
Midstream
Cleco Midstream Resources LLC, a wholly owned subsidiary of Cleco Corporation
MMBtu
Million British thermal units
Moody’s
Moody’s Investors Service
MW
Megawatt(s) as applicable
NERC
North American Electric Reliability Corporation
NOx
Nitrogen oxides
OCI
Other Comprehensive Income
Oxbow
Oxbow Lignite Company, LLC, 50% owned by Cleco Power and 50% owned by SWEPCO
PCAOB
Public Company Accounting Oversight Board
PCB
Polychlorinated biphenyl
Perryville
Perryville Energy Partners, L.L.C., a wholly owned subsidiary of Cleco Corporation
Power Purchase Agreement
Power Purchase Agreement, dated as of January 28, 2004, between Perryville and Entergy Services
PPACA
Patient Protection and Affordable Care Act (HR 3590)
PRP
Potentially responsible party
Registrant(s)
Cleco Corporation and Cleco Power
RFP
Request for Proposal
Sale Agreement
Purchase and Sale Agreement, dated as of January 28, 2004, between Perryville and Entergy Louisiana
SEC
Securities and Exchange Commission
SERP
Cleco Corporation Supplemental Executive Retirement Plan
Shaw
Shaw Contractors, Inc., a subsidiary of The Shaw Group Inc.
SO2
Sulfur dioxide
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.
Teche
Teche Electric Cooperative, Inc.
VaR
Value-at-risk
VIE
Variable Interest Entity
 
 
 
4

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
CAUTIONARY NOTE REGARDING FORWARD-LOOKING STATEMENTS

 
This Combined Quarterly Report on Form 10-Q includes “forward-looking statements” about future events, circumstances, and results.  All statements other than statements of historical fact included in this Combined Quarterly Report are forward-looking statements, including, without limitation, statements regarding Madison Unit 3; JPMVEC’s performance under the Evangeline 2010 Tolling Agreement; 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; expansion of service to certain customers and service to new customers; future environmental regulations and remediation liabilities; electric customer credits; and the anticipated outcome of various regulatory and legal proceedings.  Although the Registrants believe that the expectations reflected in such forward-looking statements are reasonable, such forward-looking statements are based on numerous assumptions (some of which may prove to be incorrect) and are subject to risks and uncertainties that could cause the actual results to differ materially from the Registrants’ expectations.  In addition to any assumptions and other factors referred to specifically in connection with these forward-looking statements, the following list identifies some of the factors that could cause the Registrants’ actual results to differ materially from those contemplated in any of the Registrants’ forward-looking statements:
 
§  
Factors affecting utility operations, such as unusual weather conditions or other natural phenomena; catastrophic weather-related damage (such as hurricanes and other storms); unscheduled generation outages; unanticipated maintenance or repairs; unanticipated changes to fuel costs; fuel supply costs or availability constraints due to higher demand, shortages, transportation problems or other developments; fuel mix of Cleco’s generation facilities; decreased customer load; environmental incidents; environmental compliance costs; and power transmission system constraints;
 
§  
Cleco Corporation’s holding company structure and its dependence on the earnings, dividends, or distributions from its subsidiaries to meet its debt obligations and pay dividends on its common stock;
 
§  
Cleco Power’s ability to operate and maintain, within its projected costs, any self-build projects identified in future IRP and RFP processes and its participation in any government grants;
 
§  
Dependence of Cleco Power for energy from sources other than its facilities and the uncertainty of future sources of such additional energy;
 
§  
Nonperformance by and creditworthiness of counterparties under tolling and power purchase agreements, or the restructuring of those agreements, including possible termination;
 
§  
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 audits and fuel audits, the formation of ICTs, and the compliance with the Electric Reliability Organization reliability standards for bulk power systems by Cleco Power and Evangeline;
 
§  
Financial or regulatory accounting principles or policies imposed by FASB, the SEC, the PCAOB, FERC, the LPSC or similar entities with regulatory or accounting oversight;
 
§  
Economic conditions, including the ability of customers to continue paying for utility bills, related growth and/or down-sizing of businesses in Cleco’s service area, monetary fluctuations, changes in commodity prices, and inflation rates;
 
§  
The current global and U.S. economic environment;
 
§  
Credit ratings of Cleco Corporation and Cleco Power;
 
§  
Ability to remain in compliance with debt covenants;
 
§  
Changing market conditions and a variety of other factors associated with physical energy, financial transactions, and energy service activities, including, but not limited to, price, basis, credit, liquidity, volatility, capacity, transmission, interest rates, and warranty risks;
 
§  
The availability and use of alternative sources of energy and technologies;
 
§  
Impact of the imposition of energy efficiency requirements or of increased conservation efforts of customers;
 
§  
Reliability of all Cleco Power and Midstream generating facilities, particularly Madison Unit 3;
 
§  
Acts of terrorism 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;
 
§  
Uncertain tax positions;
 
§  
Employee work force factors, including work stoppages and changes in key executives;
 
§  
Legal, environmental, and regulatory delays and other obstacles associated with mergers, acquisitions, reorganizations, investments in joint ventures, or other capital projects, including the joint project to upgrade the Acadiana Load Pocket transmission system, and the AMI project;
 
§  
Costs and other effects of legal and administrative proceedings, settlements, investigations, claims and other matters;
 
§  
Changes in federal, state, or local laws, and changes in tax laws or rates, or regulating policies;
 
§  
The impact of current or future environmental laws and regulations, including those related to greenhouse gases and energy efficiency, which could limit, or terminate, the 
 
 
 
5

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
operation of certain generating units, increase costs, reduce customer demand for electricity or otherwise materially adversely impact the Registrants’ financial condition or results of operations;
 
§  
Ability of Cleco Power to recover from its customers the costs of compliance with environmental laws and regulations; and
 
§  
Ability of the Dolet Hills lignite reserve to provide sufficient fuel to the Dolet Hills Power Station until at least 2026.

 
For additional 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 the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.  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.
 
 
6

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST 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, 2010.  For additional 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.”
 
 
 
7

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 

CLECO CORPORATION

Condensed Consolidated Statements of Income (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS, EXCEPT SHARE AND PER SHARE AMOUNTS)
 
2011
   
2010
 
Operating revenue
           
Electric operations
  $ 238,468     $ 252,798  
Tolling operations
    2,781       7,464  
Other operations
    12,728       10,876  
Affiliate revenue
    147       1,149  
Gross operating revenue
    254,124       272,287  
Electric customer credits
    (434 )     -  
Operating revenue, net
    253,690       272,287  
Operating expenses
               
Fuel used for electric generation
    96,968       94,582  
Power purchased for utility customers
    8,449       48,219  
Other operations
    27,662       26,654  
Maintenance
    16,809       13,837  
Depreciation
    29,098       24,253  
Taxes other than income taxes
    9,460       8,802  
Loss on sales of assets
    10       39  
Total operating expenses
    188,456       216,386  
Operating income
    65,234       55,901  
Interest income
    115       162  
Allowance for other funds used during construction
    1,978       9,805  
Equity income from investees
    611       37,847  
Gain on toll settlement
    -       148,402  
Other income
    1,205       1,079  
Other expense
    (1,318 )     (925 )
Interest charges
               
Interest charges, including amortization of debt expenses, premium, and discount, net of capitalized interest
    27,328       26,007  
Allowance for borrowed funds used during construction
    (714 )     (3,572 )
Total interest charges
    26,614       22,435  
Income before income taxes
    41,211       229,836  
Federal and state income tax expense
    12,195       79,866  
Net income
    29,016       149,970  
Preferred dividends requirements, net of tax
    12       12  
Net income applicable to common stock
  $ 29,004     $ 149,958  
                 
Average number of basic common shares outstanding
    60,576,004       60,326,020  
Average number of diluted common shares outstanding
    60,904,867       60,581,060  
Basic earnings per share
               
Net income applicable to common stock
  $ 0.48     $ 2.49  
Diluted earnings per share
               
Net income applicable to common stock
  $ 0.48     $ 2.48  
Cash dividends paid per share of common stock
  $ 0.25     $ 0.225  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               
 
 
 
8

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
CLECO CORPORATION

Condensed Consolidated Statements of Comprehensive Income (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
Net income
  $ 29,016     $ 149,970  
Other comprehensive income (loss), before tax:
               
Amortization of post-retirement benefit net income (loss) (net of tax (expense) benefit of $(148) in 2011 and $6 in 2010)
    338       (10 )
Cash flow hedges:
               
Net derivatives loss arising during the period (net of tax benefit of $108 in 2010)
    -       (173 )
Reclassification of interest expense on interest rate swap (net of tax expense of $78 in 2010)
    -       124  
Reclassification of interest expense on treasury rate lock (net of tax benefit of $34 in 2011 and $16 in 2010)
    (55 )     (25 )
Other comprehensive income (loss)
    283       (84 )
Comprehensive income, net of tax
  $ 29,299     $ 149,886  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               

 
9

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 

CLECO CORPORATION

Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Assets
           
Current assets
           
Cash and cash equivalents
  $ 137,191     $ 191,128  
Restricted cash
    5,352       14,959  
Customer accounts receivable (less allowance for doubtful accounts of $1,002 in 2011 and $1,046 in 2010)
    36,425       38,820  
Accounts receivable -  affiliate
    1,369       831  
Other accounts receivable (less allowance for doubtful accounts of $2,781 in 2011 and $2,409 in 2010)
    47,944       52,546  
Taxes receivable
    47,194       50,104  
Unbilled revenue
    32,380       44,649  
Fuel inventory, at average cost
    57,024       82,737  
Material and supplies inventory, at average cost
    50,058       48,265  
Accumulated deferred federal and state income taxes, net
    3,554       4,106  
Accumulated deferred fuel
    4,882       10,348  
Cash surrender value of company-/trust-owned life insurance policies
    51,109       49,789  
Prepayments
    4,114       6,399  
Regulatory assets - other
    12,997       13,508  
Other current assets
    2,842       661  
Total current assets
    494,435       608,850  
Property, plant and equipment
               
Property, plant and equipment
    3,828,289       3,810,896  
Accumulated depreciation
    (1,178,593 )     (1,162,456 )
Net property, plant and equipment
    2,649,696       2,648,440  
Construction work in progress
    150,804       135,785  
Total property, plant and equipment, net
    2,800,500       2,784,225  
Equity investment in investees
    87,343       86,732  
Prepayments
    5,040       5,274  
Restricted cash, less current portion
    26,304       26,089  
Regulatory assets and liabilities - deferred taxes, net  
    206,203       203,696  
Regulatory assets - other
    261,106       266,431  
Net investment in direct financing lease
    13,768       13,817  
Intangible asset
    142,903       145,374  
Other deferred charges
    20,309       20,922  
Total assets
  $ 4,057,911     $ 4,161,410  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               

 
(Continued on next page)
 
 
10

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
CLECO CORPORATION

Condensed Consolidated Balance Sheets (Unaudited) (Continued)
(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Liabilities and shareholders’ equity
           
Liabilities
           
Current liabilities
           
Short-term debt
  $ 150,000     $ 150,000  
Long-term debt due within one year
    12,683       12,269  
Accounts payable
    86,140       123,042  
Retainage
    4,535       2,726  
Accounts payable - affiliate
    1       155  
Customer deposits
    40,256       38,934  
Provision for rate refund
    10,032       9,598  
Interest accrued
    57,091       34,462  
Risk management liability, net
    7,574       9,027  
Regulatory liabilities - other
    40,502       43,562  
Deferred compensation
    8,585       7,751  
Uncertain tax positions
    63,603       31,853  
Other current liabilities
    13,059       14,302  
Total current liabilities
    494,061       477,681  
Deferred credits
               
Accumulated deferred federal and state income taxes, net
    545,333       553,211  
Accumulated deferred investment tax credits
    8,360       8,669  
Postretirement benefit obligations
    108,238       166,387  
Regulatory liabilities - other
    32,455       44,313  
Restricted storm reserve
    26,208       25,993  
Uncertain tax positions
    26,087       60,395  
Other deferred credits
    105,640       106,845  
Total deferred credits
    852,321       965,813  
Long-term debt, net
    1,377,684       1,399,709  
Total liabilities
    2,724,066       2,843,203  
Commitments and Contingencies (Note 11)
               
Shareholders’ equity
               
Preferred stock
               
Not subject to mandatory redemption, $100 par value, authorized 1,491,900 shares, issued 10,288 shares at  March 31, 2011 and December 31, 2010
    1,029       1,029  
Common shareholders’ equity
               
Common stock, $1 par value, authorized 100,000,000 shares, issued 60,644,959 and 60,539,624 shares and outstanding 60,632,569  and 60,526,126 shares at March 31, 2011, and
    December 31, 2010, respectively
    60,645       60,540  
Premium on common stock
    406,819       405,313  
Retained earnings
    876,959       863,237  
Treasury stock, at cost, 12,390 and 13,498 shares at March 31, 2011, and December 31, 2010, respectively
    (252 )     (274 )
Accumulated other comprehensive loss
    (11,355 )     (11,638 )
Total common shareholders’ equity
    1,332,816       1,317,178  
Total shareholders’ equity
    1,333,845       1,318,207  
Total liabilities and shareholders’ equity
  $ 4,057,911     $ 4,161,410  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               

 
 
11

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 

CLECO CORPORATION

Condensed Consolidated Statements of Cash Flows (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
Operating activities
           
Net income
  $ 29,016     $ 149,970  
Adjustments to reconcile net income to net cash provided by operating activities:
               
Depreciation and amortization
    48,098       37,622  
Gain on forgiveness of debt
    -       (129,870 )
Gain from equity investments
    (611 )     (37,847 )
Unearned compensation expense
    2,487       930  
Allowance for other funds used during construction
    (1,978 )     (9,805 )
Net deferred income taxes
    (13,144 )     16,361  
Deferred fuel costs
    3,030       19,864  
Cash surrender value of company-/trust-owned life insurance
    (1,141 )     (866 )
Changes in assets and liabilities:
               
Accounts receivable
    5,042       (17,889 )
Accounts and notes receivable, affiliate
    (538 )     9,109  
Unbilled revenue
    12,269       (10,967 )
Fuel, materials and supplies inventory
    23,920       6,895  
Prepayments
    2,520       1,552  
Accounts payable
    (31,823 )     (50,499 )
Accounts and notes payable, affiliate
    (154 )     (8,370 )
Customer deposits
    3,205       2,888  
Long-term receivable
    -       27,976  
Post retirement benefit obligations
    (58,149 )     (2,737 )
Regulatory assets and liabilities, net
    (12,266 )     (14,374 )
Other deferred accounts
    1,877       12,898  
Retainage payable
    1,004       (862 )
Taxes accrued
    2,958       53,835  
Interest accrued
    12,555       9,431  
Risk management assets and liabilities, net
    749       (1,814 )
Other operating
    (2,815 )     (2,639 )
Net cash provided by operating activities
    26,111       60,792  
Investing activities
               
Additions to property, plant and equipment
    (45,692 )     (183,561 )
Allowance for other funds used during construction
    1,978       9,805  
Equity investment in investees
    (9,239 )     (14,775 )
Transfer of cash from restricted accounts
    9,391       38,401  
Other investing
    216       521  
Net cash used in investing activities
    (43,346 )     (149,609 )
Financing activities
               
Change in short-term debt, net
  $ -     $ 150,000  
Retirement of long-term obligations
    (21,283 )     (101,075 )
Dividends paid on preferred stock
    (12 )     (12 )
Dividends paid on common stock
    (15,171 )     (13,595 )
Other financing
    (236 )     528  
Net cash (used in) provided by financing activities
    (36,702 )     35,846  
Net decrease in cash and cash equivalents
    (53,937 )     (52,971 )
Cash and cash equivalents at beginning of period
    191,128       145,193  
Cash and cash equivalents at end of period
  $ 137,191     $ 92,222  
Supplementary cash flow information
               
Interest paid (net of amount capitalized)
  $ 9,619     $ 12,394  
Income taxes paid
  $ 11,068     $ 1  
Supplementary non-cash investing and financing activities
               
Accrued additions to property, plant and equipment
  $ 17,155     $ 4,039  
Issuance of treasury stock – LTICP
  $ 23     $ 25  
Issuance of common stock – LTICP/ESPP 
  $ 77     $ 73  
Non-cash additions to property, plant and equipment
  $ 343     $ 152,067  
Non-cash return of investment
  $ -     $ 152,067  
Non-cash contribution to subsidiary, net of tax
  $ -     $ 225,732  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               

 
 
12

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST 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, 2010.  For additional 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.”



 
13

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
CLECO POWER

Condensed Consolidated Statements of Income (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS, EXCEPT SHARE AND PER SHARE AMOUNTS)
 
2011
   
2010
 
Operating revenue
           
Electric operations
  $ 238,468     $ 252,798  
Other operations
    12,243       10,386  
Affiliate revenue
    346       343  
Gross operating revenue
    251,057       263,527  
Electric customer credits
    (434 )     -  
Operating revenue, net
    250,623       263,527  
Operating expenses
               
Fuel used for electric generation
    96,968       94,582  
Power purchased for utility customers
    8,449       48,219  
Other operations
    25,986       24,408  
Maintenance
    15,613       11,722  
Depreciation
    27,401       22,647  
Taxes other than income taxes
    8,388       8,040  
(Gain) loss on sales of assets
    (1 )     40  
Total operating expenses
    182,804       209,658  
Operating income
    67,819       53,869  
Interest income
    113       158  
Allowance for other funds used during construction
    1,978       9,805  
Other income
    211       472  
Other expense
    (1,289 )     (906 )
Interest charges
               
Interest charges, including amortization of debt expenses, premium, and discount, net of capitalized interest
    25,116       22,315  
Allowance for borrowed funds used during construction
    (714 )     (3,572 )
Total interest charges
    24,402       18,743  
Income before income taxes
    44,430       44,655  
Federal and state income tax expense
    14,400       12,495  
Net income
  $ 30,030     $ 32,160  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               

 
14

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 

CLECO POWER

Condensed Consolidated Statements of Comprehensive Income (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
Net income
  $ 30,030     $ 32,160  
Other comprehensive income (loss), before tax:
               
Amortization of post-retirement benefit net income (loss) (net of tax (expense) benefit of $(63) in 2011 and $57 in 2010)
    186       (93 )
Cash flow hedges:
               
Net derivatives loss arising during the period (net of tax benefit of $108 in 2010)
    -       (173 )
Reclassification of interest expense on interest rate swap (net of tax expense of $78 in 2010)
    -       124  
Reclassification of interest expense on treasury rate lock (net of tax benefit of $34 in 2011 and $16 in 2010)
    (55 )     (25 )
Other comprehensive income (loss)
    131       (167 )
Comprehensive income, net of tax
  $ 30,161     $ 31,993  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               

 
15

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
CLECO POWER

Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Assets
           
Utility plant and equipment
           
Property, plant and equipment
  $ 3,571,656     $ 3,552,779  
Accumulated depreciation
    (1,104,300 )     (1,085,945 )
Net property, plant and equipment
    2,467,356       2,466,834  
Construction work in progress
    146,779       130,396  
Total utility plant, net
    2,614,135       2,597,230  
Current assets
               
Cash and cash equivalents
    124,440       184,912  
Restricted cash
    5,352       14,959  
Customer accounts receivable (less allowance for doubtful accounts of $1,002 in 2011 and $1,046 in 2010)
    36,425       38,820  
Accounts receivable – affiliate
    3,570       2,738  
Other accounts receivable (less allowance for doubtful accounts of $2,720 in 2011 and $2,349 in 2010)
    40,152       47,992  
Taxes receivable
    13,203       4,123  
Unbilled revenue
    32,380       44,649  
Fuel inventory, at average cost
    57,024       82,737  
Material and supplies inventory, at average cost
    47,587       45,913  
Accumulated deferred federal and state income taxes, net
    3,329       2,811  
Accumulated deferred fuel
    4,882       10,348  
Cash surrender value of company-owned life insurance policies
    20,040       20,051  
Prepayments
    3,253       4,944  
Regulatory assets – other
    12,997       13,508  
Other current assets
    1,483       412  
Total current assets
    406,117       518,917  
Equity investment in investee
    13,073       13,073  
Prepayments
    5,040       5,274  
Restricted cash, less current portion
    26,208       25,992  
Regulatory assets and liabilities – deferred taxes, net
    206,203       203,696  
Regulatory assets – other
    261,106       266,431  
Intangible asset
    142,903       145,374  
Other deferred charges
    18,778       19,218  
Total assets
  $ 3,693,563     $ 3,795,205  
Liabilities and member’s equity
               
Member’s equity
  $ 1,214,084     $ 1,233,923  
Long-term debt, net
    1,377,684       1,384,709  
Total capitalization
    2,591,768       2,618,632  
Current liabilities
               
Long-term debt due within one year
    12,683       12,269  
Accounts payable
    76,409       112,487  
Retainage
    4,535       2,726  
Accounts payable – affiliate
    17,298       7,945  
Customer deposits
    40,256       38,934  
Provision for rate refund
    10,032       9,598  
Interest accrued
    35,909       13,450  
Risk management liability, net
    7,574       9,027  
Regulatory liabilities - other
    40,502       43,562  
Uncertain tax positions
    33,479       -  
Other current liabilities
    10,473       9,862  
Total current liabilities
    289,150       259,860  
Commitments and Contingencies (Note 11)
               
Deferred credits
               
Accumulated deferred federal and state income taxes, net
    610,386       601,574  
Accumulated deferred investment tax credits
    8,360       8,669  
Postretirement benefit obligations
    71,831       130,757  
Regulatory liabilities - other
    32,455       44,313  
Restricted storm reserve
    26,208       25,993  
Uncertain tax positions
    20,562       54,835  
Other deferred credits
    42,843       50,572  
Total deferred credits
    812,645       916,713  
Total liabilities and member’s equity
  $ 3,693,563     $ 3,795,205  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               
 
 
16

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
CLECO POWER

Condensed Consolidated Statements of Cash Flows (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
Operating activities
           
Net income
  $ 30,030     $ 32,160  
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
               
Depreciation and amortization
    31,082       25,989  
Unearned compensation expense
    753       344  
Allowance for other funds used during construction
    (1,978 )     (9,805 )
Net deferred income taxes
    4,326       (1,131 )
Deferred fuel costs
    3,030       19,864  
Cash surrender value of company-owned life insurance
    11       (110 )
Changes in assets and liabilities:
               
Accounts receivable
    8,280       (20,597 )
Accounts and notes receivable, affiliate
    (725 )     (4,270 )
Unbilled revenue
    12,269       (10,967 )
Fuel, materials and supplies inventory
    24,038       6,932  
Prepayments
    1,927       1,279  
Accounts payable
    (31,202 )     (43,863 )
Accounts and notes payable, affiliate
    9,032       (19,147 )
Customer deposits
    3,205       2,888  
Post retirement benefit obligations
    (58,926 )     (3,403 )
Regulatory assets and liabilities, net
    (12,266 )     (14,374 )
Other deferred accounts
    1,379       5,813  
Retainage payable
    1,004       (862 )
Taxes accrued
    (9,080 )     15,758  
Interest accrued
    12,833       9,067  
Risk management assets and liabilities, net
    749       (1,814 )
Other operating
    (690 )     (1,881 )
Net cash provided by (used in) operating activities
    29,081       (12,130 )
Investing activities
               
Additions to property, plant and equipment
    (44,501 )     (30,257 )
Allowance for other funds used during construction
    1,978       9,805  
Transfer of cash from restricted accounts
    9,391       8,269  
Other investing
    395       57  
Net cash used in investing activities
    (32,737 )     (12,126 )
Financing activities
               
Retirement of long-term obligations
    (6,283 )     (5,912 )
Distribution to parent
    (50,000 )     (25,000 )
Other financing
    (533 )     (457 )
Net cash used in financing activities
    (56,816 )     (31,369 )
Net decrease in cash and cash equivalents
    (60,472 )     (55,625 )
Cash and cash equivalents at beginning of period
    184,912       138,113  
Cash and cash equivalents at end of period
  $ 124,440     $ 82,488  
Supplementary cash flow information
               
Interest paid (net of amount capitalized)
  $ 8,481     $ 9,792  
Income tax refunds received
  $ (229 )   $ -  
Supplementary non-cash investing and financing activities
               
Accrued additions to property, plant and equipment
  $ 17,233     $ 4,039  
Non-cash additions to property, plant and equipment
  $ 343     $ 304,134  
Non-cash assumption of deferred tax liability
  $ -     $ 78,402  
The accompanying notes are an integral part of the condensed consolidated financial statements.
               

 
 
17

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST 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
LPSC Fuel Audit
Cleco Corporation and Cleco Power
Note 13
Affiliate Transactions
Cleco Corporation and Cleco Power
Note 14
Evangeline Transactions
Cleco Corporation
Note 15
Acadia Unit 1 Transaction
Cleco Corporation and Cleco Power
Note 16
Subsequent Event
Cleco Corporation

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.
Cleco Corporation and Cleco Power report the investment in Oxbow on the equity method of accounting.  At March 31, 2011, Cleco Corporation reported the investment in Cajun on the equity method of accounting.  As a result, the assets and liabilities of these entities are represented by one line item corresponding to Cleco Corporation’s and Cleco Power’s equity investment in these entities.  The pre-tax results of operations of these entities are reported as equity income or loss from investees on Cleco Corporation’s and Cleco Power’s Condensed Consolidated Statements of Income.  For additional information on the operations of these entities, see Note 10 — “Variable Interest Entities.”
 
Basis of Presentation
The condensed consolidated financial statements of Cleco Corporation and Cleco Power have been prepared pursuant to the rules and regulations of the SEC.  Accordingly, certain information and note disclosures normally included in financial statements prepared in accordance with GAAP have been condensed or omitted; however, Cleco believes that the disclosures are adequate to make the information presented not misleading.
The year-end condensed consolidated balance sheet data was derived from audited financial statements, but does not include all disclosures required by GAAP.  The unaudited financial information included in the condensed consolidated financial statements of Cleco Corporation and Cleco Power reflects all adjustments of a normal recurring nature which are, in the opinion of the management of Cleco Corporation and Cleco Power, necessary for a fair statement of the financial position and the results of operations for the interim periods.  Information for interim periods is affected by seasonal variations in sales, rate changes, timing of fuel expense recovery and other factors, and is not indicative necessarily of the results that may be expected for the full fiscal year.  For additional information on recent authoritative guidance and its effect on financial results, see Note 2 — “Recent Authoritative Guidance.”
 
Property, Plant and Equipment
Property, plant and equipment consist primarily of regulated utility generation and energy transmission assets.  Regulated assets, utilized primarily for retail operations and electric transmission and distribution, are stated at the cost of construction, which includes certain materials, labor, payroll taxes and benefits, administrative and general costs, and the estimated cost of funds used during construction.  Jointly owned assets are reflected in property, plant and equipment at Cleco Power’s share of the cost to construct or purchase the assets.
Property, plant and equipment consist of:

(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Regulated utility plants
  $ 3,571,656     $ 3,552,054  
Other
    256,633       258,842  
Total property, plant and equipment
    3,828,289       3,810,896  
Accumulated depreciation
    (1,178,593 )     (1,162,456 )
Net property, plant and equipment
  $ 2,649,696     $ 2,648,440  
 
The table below discloses the plant acquisition adjustment reported in Cleco Power’s property, plant and equipment and the associated accumulated amortization reported in accumulated depreciation at March 31, 2011, and December 31, 2010.  In 2010, Cleco Power’s acquisition of Acadia Unit 1
 
 
18

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
resulted in a plant acquisition adjustment.  The plant acquisition adjustment represents the fair market value of the assets acquired in excess of their carrying value.  In January 2010, the LPSC approved the full recovery of the $304.0 million value for the acquisition of Acadia Unit 1, which includes a plant acquisition adjustment in the amount of $95.6 million.  The other plant acquisition adjustment relates primarily to the 1997 acquisition of Teche.  For additional information on the Acadia Unit 1 transaction, see Note 15 — “Acadia Unit 1 Transaction.”

(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Acadia
           
Plant acquisition adjustment
  $ 95,578     $ 95,578  
Less:  accumulated amortization
    3,449       2,653  
Net plant acquisition adjustment
  $ 92,129     $ 92,925  
Teche
               
Plant acquisition adjustment
  $ 5,359     $ 5,359  
Less:  accumulated amortization
    3,533       3,470  
Net plant acquisition adjustment
  $ 1,826     $ 1,889  
 
Restricted Cash
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 general corporate purposes.  At March 31, 2011, and December 31, 2010, $31.7 million and $41.0 million of cash, respectively, were restricted.  At March 31, 2011, restricted cash consisted of $0.1 million under the Diversified Lands mitigation escrow agreement, $1.9 million reserved at Cleco Power for GO Zone project costs, $26.2 million reserved at Cleco Power for future storm restoration costs, and $3.5 million at Cleco Katrina/Rita restricted for payment of operating expenses, interest, and principal on storm recovery bonds.  The $9.3 million net decrease in restricted cash from December 31, 2010, to March 31, 2011, is primarily due to the use of Cleco Katrina/Rita funds for a $6.3 million scheduled storm recovery bond payment made in March 2011 and the use of $4.2 million of GO Zone bond funds during the first quarter of 2011.
 
Fair Value Measurements and Disclosures
Various accounting pronouncements require certain assets and liabilities to be measured at their fair values.  Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance.  Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP.  Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the condensed consolidated balance sheets with their fair values disclosed without regard to the three levels.  For additional information about fair value levels, see Note 4 — “Fair Value Accounting.”
 
Risk Management
Market risk inherent in Cleco Power’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power and natural gas on different energy exchanges.  Cleco’s Energy Market Risk Management Policy authorizes the use of various derivative instruments, including exchange traded futures and option contracts, forward purchase and sales contracts, and swap transactions to reduce exposure to fluctuations in the price of power and natural gas.  Cleco applies the authoritative guidance as it relates to derivatives and hedging to determine whether the market risk-sensitive instruments and positions are required to be marked-to-market.  Generally, Cleco Power’s market risk-sensitive instruments and positions qualify for the normal-purchase, normal-sale exception to mark-to-market accounting because Cleco Power takes physical delivery and the instruments and positions are used to satisfy customer requirements.  Cleco Power entered into certain financial transactions it considered economic hedges to mitigate the risk associated with the fixed-price power provided to a wholesale customer through December 2010.  These transactions were marked-to-market with the resulting gain or loss recorded on the income statement as a component of operating revenue.  After December 31, 2010, no gain or loss for these transactions was recorded, as the contract had expired.  For the three months ended March 31, 2010, Cleco Power realized losses and mark-to-market losses of $0.2 million and $0.4 million, respectively, recorded in other operations revenue.  
Cleco Power has entered into other 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 risk management assets or liabilities.  Such gain or loss is deferred as a component of deferred fuel asset or liabilities.  When these positions close, actual gains or losses will be included in the fuel adjustment clause and reflected on customers’ bills as a component of the fuel cost adjustment.  Based on market prices at March 31, 2011, and December 31, 2010, the net mark-to-market impact relating to these positions were losses of $11.8 million and $15.1 million, respectively.  Deferred losses relating to closed natural gas positions totaled $1.7 million and $1.6 million at March 31, 2011, and December 31, 2010, respectively.
Cleco Power maintains margin accounts with commodity brokers used to partially fund the acquisition of natural gas futures, options, and swap contracts.  These contracts/positions are used to mitigate the risks associated with the volatility in customer fuel costs noted above.  At March 31, 2011, and December 31, 2010, Cleco Power had deposited net collateral of $3.5 million and $4.3 million, respectively, to cover requirements relating to open natural gas futures, options, and swap positions.  The current and long-term portions of collateral are reported as a component of risk management assets or liabilities and other deferred credits, respectively.
Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, counterparty credit exposure, and
 
 
19

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
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.  
In August 2009, Cleco Power entered into a $50.0 million bank loan with variable interest, paid monthly, calculated at 3.00% plus the one-month LIBOR.  The loan was set to mature on August 19, 2012.  In order to mitigate the risk of future floating interest rates, Cleco Power entered into an interest rate swap in the third quarter of 2009.  Based on the notional amount of the bank loan, the swap required a monthly net settlement between Cleco Power’s fixed payment of 1.84% and the swap counterparty’s floating payment of the one-month LIBOR.  The swap was set to mature on May 31, 2012.  Under the authoritative guidance for derivatives and hedging, the swap met the criteria of a cash flow hedge.  Changes in the swap’s fair value related to the effective portion of cash flow hedges were recognized in other comprehensive income, whereas changes in the fair value related to the ineffective portion were recognized in earnings.  As settlements were made, the swap’s other comprehensive income fair values were reclassified into earnings as a component of interest expense.  In November 2010, Cleco Power terminated the interest rate swap and repaid in full the associated $50.0 million bank loan.  At the time of the termination, the remaining $1.1 million of losses in accumulated other comprehensive income were reclassified to other expense.  For the three months ended March 31, 2010, there were $0.2 million of reclassification adjustments from accumulated other comprehensive loss to interest expense as a result of monthly settlements.  There was no impact to earnings due to ineffectiveness for the three months ended March 31, 2010.  For additional information on accounting for derivatives, see Note 4 — “Fair Value Accounting.”
 
Reclassifications
Cleco’s and Cleco Power’s Consolidated Statements of Cash Flows for the three months ended March 31, 2010, have been adjusted as shown below as a result of an error in the presentation of cash flows related to the accruals for property, plant and equipment.  These adjustments had no impact on the Registrants’ financial condition or results of operations as of March 31, 2010.  Management believes that these adjustments did not have a material effect on the Registrants’ Consolidated Statements of Cash Flows for the three months ended March 31, 2010.  Management is continuing to assess the impact of this matter on the Registrants’ prior periods Consolidated Statements of Cash Flows.  The adjustments to the Consolidated Statements of Cash Flows for the three months ended March 31, 2010 are presented in the following tables.
 

(THOUSANDS)
 
AS REPORTED
   
AS ADJUSTED
 
Cleco Corporation
           
Accounts payable
  $ (58,264 )   $ (50,499 )
Retainage payable
  $ (59 )   $ (862 )
Net cash provided by operating activities
  $ 53,830     $ 60,792  
Additions to property, plant and equipment
  $ (176,599 )   $ (183,561 )
Net cash used in investing activities
  $ (142,647 )   $ (149,609 )
Net decrease in cash and cash equivalents
  $ (52,971 )   $ (52,971 )
Cash and cash equivalents at the beginning of the period
  $ 145,193     $ 145,193  
Cash and cash equivalents at the end of the period
  $ 92,222     $ 92,222  
Accrued additions to property, plant and equipment
  $ 5,194     $ 4,039  

(THOUSANDS)
 
AS REPORTED
   
AS ADJUSTED
 
Cleco Power
           
Accounts payable
  $ (51,628 )   $ (43,863 )
Retainage payable
  $ (59 )   $ (862 )
Net cash provided by operating activities
  $ (19,092 )   $ (12,130 )
Additions to property, plant and equipment
  $ (23,295 )   $ (30,257 )
Net cash used in investing activities
  $ (5,164 )   $ (12,126 )
Net decrease in cash and cash equivalents
  $ (55,625 )   $ (55,625 )
Cash and cash equivalents at the beginning of the period
  $ 138,113     $ 138,113  
Cash and cash equivalents at the end of the period
  $ 82,488     $ 82,488  
Accrued additions to property, plant and equipment
  $ 5,194     $ 4,039  
 
 
Earnings per Average Common Share
The following table shows the calculation of basic and diluted earnings per share.

                     
FOR THE THREE MONTHS ENDED MARCH 31,
 
               
2011
               
2010
 
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)
 
INCOME
   
SHARES
   
PER SHARE
AMOUNT
   
INCOME
   
SHARES
   
PER SHARE
AMOUNT
 
Income from continuing operations
  $ 29,016                 $ 149,970              
Deduct:  non-participating stock dividends (4.5% preferred stock)
    12                   12              
Basic net income applicable to common stock
  $ 29,004       60,576,004     $ 0.48     $ 149,958       60,326,020     $ 2.49  
Effect of dilutive securities
                                               
Add:  stock option grants
            22,701                       39,156          
Add:  restricted stock (LTICP)
            306,162                       215,884          
Diluted net income applicable to common stock
  $ 29,004       60,904,867     $ 0.48     $ 149,958       60,581,060     $ 2.48  
 
 
 
20

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
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 months ended March 31, 2011 and 2010, due to the average market price being higher than the exercise prices of the stock options.  

Stock-Based Compensation
At March 31, 2011, 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.  
On January 28, 2011, Cleco granted 145,002 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
 
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
   
2011
   
2010
 
Equity classification
                       
Non-vested stock
  $ 1,151     $ 661     $ 322     $ 170  
Stock options
    13       13       -       -  
Total equity classification
  $ 1,164     $ 674     $ 322     $ 170  
Liability classification
                               
Common stock equivalent units
  $ 1,194     $ 149     $ 431     $ 174  
Total pre-tax compensation expense
  $ 2,358     $ 823     $ 753     $ 344  
Tax benefit (excluding income tax gross-up)
  $ 907     $ 317     $ 290     $ 132  
 
 
Note 2 — Recent Authoritative Guidance

The Registrants adopted, or will adopt, the recent authoritative guidance listed below on their respective effective dates.
In May 2010, FASB amended the authoritative guidance pertaining to compensation in order to clarify the issuance of stock options in currencies other than the ones in which employees are normally paid.  This amendment was effective for reporting periods that began on or after December 15, 2010.  The adoption of this amendment did not have an impact on the financial condition or results of operations of the Registrants.
In July 2010, FASB amended the authoritative guidance on receivables, which required companies to improve their disclosures about the credit quality of their financing receivables and the credit reserves held against them.  For public companies, the amendment was effective for interim and annual reporting periods ending on or after December 15, 2010, with specific items, such as allowance rollforward and modification disclosures, effective for periods beginning after December 15, 2010.  The adoption of this amendment did not have any effect on the financial condition or results of operations of the Registrants.
In December 2010, FASB amended the authoritative guidance on business combinations to expand supplemental pro forma disclosures and to require comparative prior period financial statement disclosures as if the combination occurred as of the beginning of the prior annual period.  The amendment was effective prospectively for business combination acquisition dates on or after the beginning of the first annual reporting period beginning on or after December 15, 2010.  The adoption of this amendment did not have any effect on the financial condition or results of operations of the Registrants.
 
Note 3 — Regulatory Assets and Liabilities

Cleco Power follows the authoritative guidance on regulated operations, which allows utilities to capitalize or defer certain costs based on regulatory approval and management’s ongoing assessment that it is probable these items will be recovered through the ratemaking process.
The following chart summarizes Cleco Power’s regulatory assets and liabilities at March 31, 2011, and December 31, 2010:
 
   
AT MARCH 31,
   
AT DECEMBER 31,
 
(THOUSANDS)
 
2011
   
2010
 
Regulatory assets and liabilities – deferred taxes, net
  $ 206,203     $ 203,696  
Deferred mining costs
  $ 21,029     $ 21,666  
Deferred interest costs
    6,941       7,033  
Deferred asset removal costs
    783       768  
Deferred postretirement plan costs
    116,267       117,651  
Deferred tree trimming costs
    10,407       11,086  
Deferred training costs
    7,603       7,642  
Deferred storm surcredits, net
    10,754       10,633  
Deferred construction carrying costs
    15,840       18,830  
Lignite mining agreement contingency
    3,781       3,781  
AFUDC equity gross-up
    75,018       74,859  
Deferred rate case costs
    1,520       1,654  
Deferred Acadia Unit 1 acquisition costs
    3,050       3,076  
Deferred IRP/RFP costs
    859       977  
Deferred AMI pilot costs
    251       283  
Total regulatory assets – other
  $ 274,103     $ 279,939  
Deferred construction carrying costs
    (72,957 )     (87,875 )
Deferred fuel and purchased power
    4,882       10,348  
Total regulatory assets and liabilities, net
  $ 412,231     $ 406,108  
 
 
 
21

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
Deferred Construction Carrying Costs
In February 2006, the LPSC approved Cleco Power’s plans to build Madison Unit 3.  Terms of the approval included authorization for Cleco Power to collect from customers an amount equal to 75% of the LPSC-jurisdictional portion of the carrying costs of capital during the construction phase of the unit.  In any calendar year during the construction period, the amount collected from customers is not to exceed 6.5% of Cleco Power’s projected retail revenues.  Cleco Power began collection of the carrying costs and established a regulatory liability in May 2006.  In October 2009, the LPSC voted unanimously to approve Cleco Power’s retail rate plan.  The retail rate plan established that Cleco Power return $183.2 million of carrying costs to customers over a five-year period and record a regulatory asset for all carrying costs incurred by Cleco Power above the actual amount collected from customers.  On February 12, 2010, Madison Unit 3 commenced commercial operation and the new rates became effective.  At that time, Cleco Power began returning the construction carrying costs to customers and amortizing the regulatory asset over a five-year period.  In March 2010, the LPSC issued an order changing the period of return from five years to four years and established that Cleco Power return approximately $167.0 million over the four-year period.  At March 31, 2011, the regulatory liability and the related regulatory asset were $73.0 million and $15.8 million, respectively.  As of March 31, 2011, Cleco Power had returned $93.7 million to customers.  At March 31, 2011, $40.5 million was due to be returned to customers within one year.  
 
Deferred 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 fuel adjustment clause, which enables Cleco Power to pass on to its customers substantially all such charges.  For the three months ended March 31, 2011, approximately 90% of Cleco Power’s total fuel cost was regulated by the LPSC, while the remainder was regulated by FERC.  The $5.5 million decrease in the under-recovered costs was primarily the result of $2.2 million in collections of previously deferred fuel and purchased power costs and a $3.3 million decrease in mark-to-market losses on gas positions, which was primarily due to the contractual expiration of certain positions.
 
Note 4 — Fair Value Accounting

The amounts reflected in Cleco Corporation and Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2011, and December 31, 2010, for 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 and Cleco’s nonconvertible preferred stock 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 and by Cleco for preferred stock with similar maturities.
 
Cleco
   
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
(THOUSANDS)
 
CARRYING
VALUE
   
ESTIMATED
FAIR VALUE
   
CARRYING
VALUE
   
ESTIMATED
FAIR VALUE
 
Financial instruments not marked-to-market
                       
Cash and cash equivalents
  $ 137,191     $ 137,191     $ 191,128     $ 191,128  
Restricted cash
  $ 31,656     $ 31,656     $ 41,048     $ 41,048  
Long-term debt, excluding debt issuance costs
  $ 1,382,553     $ 1,442,300     $ 1,403,836     $ 1,462,063  
Preferred stock not subject to mandatory redemption
  $ 1,029     $ 833     $ 1,029     $ 844  
 
Cleco Power
   
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
(THOUSANDS)
 
CARRYING
VALUE
   
ESTIMATED
FAIR VALUE
   
CARRYING
VALUE
   
ESTIMATED
FAIR VALUE
 
Financial instruments not marked-to-market
                       
Cash and cash equivalents
  $ 124,440     $ 124,440     $ 184,912     $ 184,912  
Restricted cash
  $ 31,560     $ 31,560     $ 40,951     $ 40,951  
Long-term debt, excluding debt issuance costs
  $ 1,382,553     $ 1,442,300     $ 1,388,836     $ 1,447,063  
 
At March 31, 2011, Cleco and Cleco Power were exposed to concentrations of credit risk through their short-term investments classified as cash equivalents and restricted cash.  Cleco had $160.9 million ($129.2 million of cash and $31.7 million of restricted cash) in short-term investments in institutional money market funds.  If the money market funds failed to perform under the terms of the investment, Cleco would be exposed to a loss of the invested amounts.  Cleco Power had $149.6 million ($118.0 million of cash and $31.6 million of restricted cash) in short-term investments in institutional money market funds.  If the money market funds failed to perform under the terms of the investments, Cleco Power would be exposed to a loss of the invested amounts.  Collateral on these types of investments is not required by either Cleco or Cleco Power.  In order to mitigate potential credit risk, Cleco and Cleco Power have established guidelines for short-term investments.  Money market funds must have at least $1.0 billion in assets under management; must have been in existence for not less than two years; must have portfolios not comprised of more than 50% of securities issued by foreign entities; and must be rated in the top two ratings categories by at least one nationally recognized rating agency.  Commercial paper must be issued by a company with headquarters in the U.S. and rated not less than A1 by Standard & Poor’s or P1 by
 
 
22

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
Moody’s.  For split-rated issuers, the second rating must not be lower than either A2 or P2; the issuer’s long-term debt must be rated not lower than A by Standard & Poor’s or A2 by Moody’s; and the issuer cannot be on negative credit watch.  Investments in commercial paper rated A2 by Standard & Poor’s or P2 by Moody’s may be made if approved by the appropriate level of management.  

Interest Rate Swap
In August 2009, Cleco Power entered into a $50.0 million bank loan with variable interest, paid monthly, and calculated at 3.00% plus the one-month LIBOR.  In order to mitigate the risk of future floating interest rates, Cleco Power entered into an interest rate swap in the third quarter of 2009.  Based on the notional amount of the bank loan, the swap required a monthly net settlement between Cleco Power’s fixed payment of 1.84% and the swap counterparty’s floating payment of the one-month LIBOR.  Both the bank loan and the swap were effective the same day and required monthly payments on the same day near the end of the month.  From the inception of the loan to the termination of the loan, Cleco Power recognized net interest expense equal to an annual rate of 4.84% on the bank loan.  Since both the bank loan and the swap required payments on the same day near the end of the month, the cash payments were materially close to the interest expense recognized.  
The swap met the criteria of a cash flow hedge under the authoritative guidance as it related to derivatives and hedging.  Changes in the swap’s fair value related to the effective portion were recognized in other comprehensive income.  As settlements were made, the swap’s other comprehensive income fair values were reclassified into earnings as a component of interest expense.  For the three months ended March 31, 2010, there were $0.2 million of reclassification adjustments from accumulated other comprehensive loss to interest expense as a result of monthly settlements.  There was no impact to earnings due to ineffectiveness for the three months ended March 31, 2010.  In November 2010, Cleco Power terminated the interest rate swap and repaid in full the associated $50.0 million bank loan and all remaining losses in accumulated other comprehensive loss were reclassified to other expense.  
 
Fair Value Measurements and Disclosures
The authoritative guidance on fair value measurements requires entities to classify assets and liabilities measured at their fair value according to three different levels depending on the inputs used in determining fair value.
The tables below disclose for Cleco and Cleco Power the fair value of financial assets and liabilities measured on a recurring basis and within the scope of the authoritative guidance for fair value measurements and disclosures.

 
Cleco
   
CLECO CONSOLIDATED FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
 
(THOUSANDS)
 
AT MARCH 31, 2011
   
QUOTED PRICES IN
ACTIVE MARKETS
FOR IDENTICAL
ASSETS
(LEVEL 1)
   
SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2)
   
SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3)
   
AT DECEMBER 31, 2010
   
QUOTED PRICES IN
ACTIVE MARKETS
FOR IDENTICAL
ASSETS
(LEVEL 1)
   
SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2)
   
SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3)
 
Asset Description
                                               
Energy market derivatives
  $ 7     $ -     $ 7     $ -     $ 97     $ -     $ 97     $ -  
Institutional money market funds
    160,856       -       160,856       -       229,748       -       229,748       -  
Total assets
  $ 160,863     $ -     $ 160,863     $ -     $ 229,845     $ -     $ 229,845     $ -  
Liability Description
                                                               
Energy market derivatives
  $ 11,856     $ 2,729     $ 9,127     $ -     $ 15,245     $ 3,317     $ 11,928     $ -  
Total liabilities
  $ 11,856     $ 2,729     $ 9,127     $ -     $ 15,245     $ 3,317     $ 11,928     $ -  
 
Cleco Power
   
CLECO POWER FAIR VALUE MEASUREMENTS AT REPORTING DATE USING:
 
(THOUSANDS)
 
AT MARCH 31, 2011
   
QUOTED PRICES IN
ACTIVE MARKETS
FOR IDENTICAL
ASSETS
(LEVEL 1)
   
SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2)
   
SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3)
   
AT DECEMBER 31, 2010
   
QUOTED PRICES IN
ACTIVE MARKETS
FOR IDENTICAL
ASSETS
(LEVEL 1)
   
SIGNIFICANT
OTHER
OBSERVABLE
INPUTS
(LEVEL 2)
   
SIGNIFICANT
UNOBSERVABLE
INPUTS
(LEVEL 3)
 
Asset Description
                                               
Energy market derivatives
  $ 7     $ -     $ 7     $ -     $ 97     $ -     $ 97     $ -  
Institutional money market funds
    149,560       -       149,560       -       224,451       -       224,451       -  
Total assets
  $ 149,567     $ -     $ 149,567     $ -     $ 224,548     $ -     $ 224,548     $ -  
Liability Description
                                                               
Energy market derivatives
  $ 11,856     $ 2,729     $ 9,127     $ -     $ 15,245     $ 3,317     $ 11,928     $ -  
Total liabilities
  $ 11,856     $ 2,729     $ 9,127     $ -     $ 15,245     $ 3,317     $ 11,928     $ -  

 
 
23

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
The derivative assets and liabilities are classified as either current or non-current depending on when the positions close.  All energy market derivative current assets and current liabilities are reported as a net current risk management asset or liability.  All energy market derivative non-current assets and non-current liabilities are reported net in other deferred charges or other deferred credits.  Net presentation is appropriate due to the right of offset included in the master netting agreements.  On the balance sheet, the net current and net non-current derivative positions are netted with the applicable margin deposits.  At March 31, 2011, a net current risk management liability of $7.6 million represented the current derivative positions of $11.1 million reduced by current margin deposits of $3.5 million and option premiums that were less than $0.1 million.  The non-current liability derivative positions of $0.7 million were recorded in other deferred credits.  The institutional money market funds were reported on the Cleco Condensed Consolidated balance sheet in cash and cash equivalents, current restricted cash, and non-current restricted cash in the amounts of $129.2 million, $5.4 million, and $26.3 million, respectively.  At Cleco Power, cash and cash equivalents, current restricted cash, and non-current restricted cash were $118.0 million, $5.4 million, and $26.2 million, respectively, as of March 31, 2011.  
Cleco utilizes different valuation techniques for fair value calculations.  In order to measure the fair value for Level 1 assets and liabilities, Cleco obtains the closing price from published indices in active markets for the various instruments and multiplies this price by the appropriate number of instruments held.  Level 2 fair values for assets and liabilities are determined by obtaining the closing price from published indices in active markets for instruments that are similar to Cleco’s assets and liabilities.  The fair value obtained is then discounted to the current period using a U.S. Treasury published interest rate as a proxy for a risk-free rate of return.  For some options, Cleco uses the Black-Scholes model using observable and available inputs to calculate the fair value, consistent with the income approach.  These techniques have been applied consistently from fiscal period to fiscal period.  Level 3 fair values allow for situations in which there is little, if any, market activity for the asset or liability at the measurement date.  Cleco had no Level 3 assets or liabilities at March 31, 2011, or December 31, 2010.
The assets and liabilities reported at fair value are grouped into classes based on the underlying nature and risks associated with the individual asset or liability.  Level 1 of energy market derivative assets and liabilities consists of a single class that includes natural gas futures with quoted prices on a liquid, national exchange.  As the future price of natural gas is affected by market expectations, such as the supply of natural gas relative to demand, the fair value of Cleco’s natural gas futures fluctuates.
Level 2 of energy market derivative assets and liabilities consists of two classes.  The first class contains natural gas swaps which fluctuate in value as the underlying natural gas futures fair value changes, and as market interest rates change. Cleco records the natural gas swaps at the net present value.  The second class consists of natural gas options.  The fair value of natural gas options fluctuates with the volatility in the fair value of natural gas, the number of days until the options expire, the underlying natural gas futures price fluctuations, and market interest rates.  Cleco records natural gas options at the net present value.  Both of these energy market derivative classes also contain counterparty execution risk because the transactions are entered into with a direct counterparty and are not traded through an exchange.
The Level 2 institutional money market funds asset consists of a single class.  In order to capture interest income and minimize risk, cash is invested in money market funds that invest primarily in short-term securities issued by the U.S. Treasury in order to maintain liquidity and achieve the goal of a net asset value of a dollar.  The risks associated with this class are counterparty risk of the fund manager and risk of price volatility associated with the underlying securities of the fund.
Cleco has a policy that transfers between Levels 1, 2, and 3 are recognized at the end of a reporting period.  During the three months ended March 31, 2011, and the year ended December 31, 2010, Cleco did not experience any transfers between levels.
 
Derivatives and Hedging
The authoritative guidance on derivatives and hedging requires entities to provide transparency 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 disclosures about derivative fair value, gains and losses, and credit-risk-related contingent features in derivative agreements.  

The following table presents the fair values of derivative instruments and their respective line items as recorded on Cleco Corporation and Cleco Power’s Condensed Consolidated Balance Sheets as of March 31, 2011, and December 31, 2010:

 
DERIVATIVES NOT DESIGNATED AS HEDGING INSTRUMENTS
 
 
LIABILITY DERIVATIVES
 
(THOUSANDS)
FAIR VALUE
BALANCE SHEET LINE ITEM
 
AT MARCH 31, 2011
   
DECEMBER 31, 2010
 
Commodity contracts
             
Fuel cost hedges:
             
Current
Risk management liability, net
  $ (11,147 )   $ (13,497 )
Long-term
Other deferred credits
    (702 )     (1,651 )
Total
    $ (11,849 )   $ (15,148 )
 
The following table presents the effect of derivatives not designated as hedging instruments on Cleco Corporation and Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2011, and 2010:
 
 
24

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 

     
FOR THE THREE MONTHS ENDED MARCH 31,
 
     
2011
   
2010
 
(THOUSANDS)
LOSS IN INCOME OF
DERIVATIVES LINE ITEM
 
AMOUNT OF LOSS
RECOGNIZED IN
INCOME ON
DERIVATIVES
   
AMOUNT OF LOSS
RECOGNIZED IN
INCOME ON
DERIVATIVES
 
Commodity contracts
             
Economic hedges
Other operations revenue
  $ -     $ 602 (1)
Fuel cost hedges(2)
Fuel used for electric generation
    3,794       7,814  
Total
    $ 3,794     $ 8,416  
(1)For the three months ended March 31, 2010, Cleco recognized $0.4 million of mark-to-market losses, respectively, related to economic hedges.
 
(2)In accordance with the authoritative guidance for regulated operations, an additional $11.8 million of unrealized losses and $1.7 million of deferred losses associated with fuel cost hedges are reported in Accumulated Deferred Fuel on the balance sheet as of March 31, 2011, compared to $15.1 million of unrealized losses and $1.6 million of deferred losses associated with fuel cost hedges as of December 31, 2010. As gains and losses are realized in future periods, they will be recorded as Fuel Used for Electric Generation on the Income Statement.
 
 
At March 31, 2011, Cleco Power had 8.0 million MMBtus hedged for natural gas fuel costs, which is approximately 10% of the estimated natural gas requirements for a two-year period.  At December 31, 2010, Cleco Power had 9.4 million MMBtus hedged or approximately 11% of gas requirements for a two-year period.  
The following table presents the effect of derivatives designated as hedging instruments on Cleco Corporation and Cleco Power’s Condensed Consolidated Statements of Income for the three months ended March 31, 2011, and 2010:

         
FOR THE THREE MONTHS ENDED MARCH 31,
 
   
2011
   
2010
 
(THOUSANDS)
 
AMOUNT OF (LOSS) GAIN
RECOGNIZED IN OCI
   
AMOUNT OF (LOSS)
GAIN RECLASSIFIED
FROM ACCUMULATED
OCI INTO INCOME
(EFFECTIVE PORTION)
   
AMOUNT OF (LOSS) GAIN
RECOGNIZED IN OCI
   
AMOUNT OF (LOSS)
GAIN RECLASSIFIED
FROM ACCUMULATED
OCI INTO INCOME
(EFFECTIVE PORTION)
 
Interest rate swap(1)
  $ -     $ - *   $ (281 )   $ (202 )*
Treasury rate locks
  $ -     $ 89 *   $ -     $ 41  
* The (loss) gain reclassified from accumulated OCI into income (effective portion) is reflected in interest charges.
                         
(1) In November 2010, the interest rate swap was terminated.
 
 
At March 31, 2011, Cleco Power expected $0.4 million of the effective portion of treasury rate locks cash flow hedges to be reclassed from accumulated OCI to a reduction in interest charges over the next 12 months.  
 
Note 5 — Debt

 
Short-term Debt
At March 31, 2011, and at December 31, 2010, Cleco had $150.0 million of short-term debt outstanding. The short-term debt outstanding was a bank term loan Cleco Corporation entered into in February 2010.  The bank term loan had an interest rate of LIBOR plus 2.75% and was set to mature in February 2011.  In January 2011, Cleco extended the bank term loan to mature August 19, 2011 and lowered the interest rate to LIBOR plus 2.50% or ABR plus 1.50%.  At March 31, 2011, the interest rate on the term loan was 4.75%.  On April 29, 2011, Cleco repaid the $150.0 million bank term loan.  As part of the repayment, Cleco paid $0.6 million for accrued interest on the term loan.
Cleco Power had no short-term debt outstanding at March 31, 2011, or December 31, 2010.
 
Long-term Debt
At March 31, 2011, Cleco’s long-term debt outstanding was $1.4 billion, of which $12.7 million was due within one year, compared to $1.4 billion outstanding at December 31, 2010, of which $12.3 million was due within one year.  The long-term debt due within one year at March 31, 2011, represents principal payments for the Cleco Katrina/Rita storm recovery bonds scheduled to be paid in the next twelve months.  For Cleco, long-term debt decreased $21.6 million primarily due to a $15.0 million repayment of Cleco’s credit facility draws and $6.3 million related to a scheduled Cleco Katrina/Rita storm recovery bond principal payment made in March 2011.  
At March 31, 2011, Cleco Power’s long-term debt outstanding was $1.4 billion, of which $12.7 million was due within one year, compared to $1.4 billion outstanding at December 31, 2010, of which $12.3 million was due within one year.  The long-term debt due within one year at March 31, 2011, represents principal payments for the Cleco Katrina/Rita storm recovery bonds scheduled to be paid in the next twelve months.  For Cleco Power, long-term debt decreased $6.6 million primarily due to $6.3 million related to a scheduled Cleco Katrina/Rita storm recovery bond principal payment made in March 2011.  
 
Note 6 — Pension Plan and Employee Benefits

 
Pension Plan and Other Benefits Plan
Most employees hired before August 1, 2007 are covered by a non-contributory, defined benefit pension plan.  Benefits under the plan reflect an employee’s years of service, age at retirement, and highest total average compensation for any consecutive five calendar years during the last 10 years of employment with Cleco Corporation.  Cleco Corporation’s policy is to base its contributions to the employee pension plan upon actuarial computations utilizing the projected unit credit method, subject to the IRS’s full funding limitation.  During January 2011, Cleco made $60.0 million in discretionary
 
 
25

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 

contributions to the pension plan, with $40.1 million designated for the 2010 plan year and the remaining $19.9 million designated for the 2011 plan year.  Cleco Power expects to be required to make approximately $4.9 million in additional contributions to the pension plan over the next five years, none of which are required for the 2011 plan year.  The required contributions are driven by liability funding target percentages set by law which could cause the required contributions to be uneven among the years.  The ultimate amount and timing of the contributions may be affected by changes in the discount rate, changes in the funding regulations, and actual returns on fund assets.  Cleco Power is considered the plan sponsor, and Support Group is considered the plan administrator.  
Cleco Corporation’s retirees and their dependents are eligible to receive medical, dental, vision, and life insurance benefits (other benefits).  Cleco Corporation recognizes the expected cost of these other benefits during the periods in which the benefits are earned.
The components of net periodic pension and other benefit cost for the three months ended March 31, 2011, and 2010, are as follows:

   
PENSION BENEFITS
   
OTHER BENEFITS
 
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
   
2011
   
2010
 
Components of periodic benefit costs
                       
Service cost
  $ 2,052     $ 1,753     $ 379     $ 383  
Interest cost
    4,392       4,113       460       499  
Expected return on plan assets
    (5,512 )     (4,866 )     -       -  
Transition obligation
    -       -       5       5  
Prior period service cost
    (18 )     (18 )     (52 )     (505 )
Net loss
    1,403       483       257       250  
Net periodic benefit cost
  $ 2,317     $ 1,465     $ 1,049     $ 632  
 
Since Cleco Power is the pension plan sponsor and the related trust holds the assets, the net unfunded status of the pension plan is reflected at Cleco Power.  The liability of Cleco Corporation’s other subsidiaries is transferred, with a like amount of assets, to Cleco Power monthly.  The expenses of the pension plan related to Cleco Corporation’s other subsidiaries for both the three-month periods ended March 31, 2011, and 2010, were $0.5 million.  
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.  At both March 31, 2011, and December 31, 2010, the current portion of the other benefits liability for Cleco was $3.0 million.  At both March 31, 2011, and December 31, 2010, the current portion of the other benefits liability for Cleco Power was $2.8 million.  The expense related to other benefits reflected in Cleco Power’s Condensed Consolidated Statements of Income for the three-month periods ended March 31, 2011, and 2010, was $0.9 million and $0.5 million, respectively.  Cleco Power’s allocated amount of the other benefit liability was $32.4 million and $32.3 million at March 31, 2011, and December 31, 2010, respectively.
In March 2010, the President signed the PPACA, a comprehensive health care law.  While the provisions of the PPACA are not effective immediately, the provisions could increase the Registrants’ retiree medical unfunded liability and related expenses before the effective date.  Management will continue to monitor this law and its possible impact on the Registrants.  
 
SERP
Certain Cleco executive officers are covered by the SERP.  The SERP is a non-qualified, non-contributory, defined benefit pension plan.  Benefits under the plan reflect an employee’s years of service, age at retirement, and the sum of the highest base salary paid out of the last five calendar years and the average of the three highest bonuses paid during the 60 months prior to retirement, reduced by benefits received from any other defined benefit pension plan, SERP Plan or Cleco contributions under the enhanced 401(k) Plan to the extent such contributions exceed the limits of the 401(k) Plan.  Cleco Corporation does not fund the SERP liability, but instead pays for current benefits out of the general funds available.  Cleco Power has formed a Rabbi Trust designated as the beneficiary for life insurance policies issued on the SERP participants.  Proceeds from the life insurance policies are expected to be used to pay the SERP participants’ life insurance benefits, as well as future SERP payments.  However, since SERP is a non-qualified plan, the assets of the trust could be used to satisfy general creditors of Cleco 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 three months ended March 31, 2011, and 2010.  Cleco Power is considered the plan sponsor, and Support Group is considered the plan administrator.
The components of the net SERP cost are as follows:

   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
Components of periodic benefit costs
           
Service cost
  $ 450     $ 348  
Interest cost
    525       525  
Prior period service cost amortization
    14       13  
Net loss amortization
    262       221  
Net periodic benefit cost
  $ 1,251     $ 1,107  
 
The SERP liabilities are reported on the individual subsidiaries’ financial statements.  At March 31, 2011, and December 31, 2010, the current portion of the SERP liability for Cleco was $1.8 million and $2.0 million, respectively.  At March 31, 2011, and December 31, 2010, the current portion of the SERP liability for Cleco Power was $0.7 million and $0.6 million, respectively.  The expense related to the SERP reflected on Cleco Power’s Condensed Consolidated Statements of Income for both three-month periods ended March 31, 2011, and 2010, was $0.3 million.  
 
401(k) Plan
Most employees are eligible to participate in the 401(k) Plan.  Since January 2008, Cleco Corporation has made matching contributions and funded dividend reinvestments with cash.
 
 
26

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 

   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
401(k) Plan expense
  $ 1,201     $ 1,030  
 
Cleco Power is the plan sponsor for the 401(k) Plan.  The expense of the 401(k) Plan related to Cleco Corporation’s other subsidiaries for both three-month periods ended March 31, 2011, and 2010, was $0.3 million.  
 
Note 7 — Income Taxes

The following table summarizes the effective income tax rates for Cleco Corporation and Cleco Power for the three-month periods ended March 31, 2011, and March 31, 2010.

 
FOR THE THREE MONTHS ENDED MARCH 31,
 
2011
 
2010
Cleco Corporation
29.6%
 
34.7%
Cleco Power
32.4%
 
28.0%
 
 
Effective Tax Rates
For the three months ended March 31, 2011, and 2010, the effective income tax rates for Cleco Corporation and Cleco Power are different than the federal statutory rate due to permanent tax deductions, flow-through of tax benefits associated with AFUDC equity and state tax expense.
 
Valuation Allowance
A deferred tax asset of $2.7 million associated with $7.7 million of capital loss carryforwards was reflected on the Condensed Consolidated Balance Sheets of both Cleco and Cleco Power at March 31, 2011, and December 31, 2010.  If the capital loss carryforwards are not utilized, $4.1 million will expire in 2011, $1.5 million will expire in 2013, $1.4 million will expire in 2014, and $0.7 million will expire in 2015.  A $1.2 million valuation allowance against the $2.7 million deferred tax asset on capital loss carryforwards was reflected on the Condensed Consolidated Balance Sheets of both Cleco and Cleco Power at March 31, 2011, and December 31, 2010.  It is possible that the valuation allowance could decrease by a maximum of $1.2 million in 2011 due to changes in expected taxable capital gains for tax year 2011.  A potential change to the valuation allowance is not expected to have a material effect on the Registrants’ annual effective tax rates.
 
Uncertain Tax Positions
Effective January 1, 2007, Cleco adopted the provisions of the authoritative guidance on accounting for uncertain tax positions.  With this adoption, Cleco classified all interest related to uncertain tax positions as a component of interest payable and interest expense.  The total amount of interest associated with uncertain tax positions at March 31, 2011, and December 31, 2010, recognized on Cleco Corporation’s Consolidated Balance Sheets was $42.6 million and $41.0 million, respectively.  The total amount of interest associated with uncertain tax positions at March 31, 2011, and December 31, 2010, recognized on Cleco Power’s Balance Sheets was $16.0 million and $15.2 million, respectively.  The total amount of interest expense related to uncertain tax positions for the periods ended March 31, 2011, and 2010, recognized on Cleco Corporation’s Condensed Consolidated Statements of Income was $1.6 million and $1.2 million, respectively.  The total amount of interest expense related to uncertain tax positions for the periods ended March 31, 2011 and 2010 recognized on Cleco Power’s Condensed Consolidated Statements of Income was $0.8 million and $0.5 million, respectively.  The total liability for unrecognized tax benefits for Cleco Corporation and Cleco Power at March 31, 2011, and December 31, 2010, are shown in the following tables:
 
Cleco
(THOUSANDS)
 
LIABILITY FOR UNRECOGNIZED
TAX BENEFITS
 
Balance at December 31, 2010
  $ 102,785  
Reduction for tax positions of current period
    (1,982 )
Additions for tax positions of prior periods
    -  
Reduction for tax positions of prior periods
    (877 )
Reduction for settlement with taxing authority
    -  
Reduction for lapse of statute of limitations
    -  
Balance at March 31, 2011
  $ 99,926  
 
Cleco Power
(THOUSANDS)
 
LIABILITY FOR UNRECOGNIZED
TAX BENEFITS
 
Balance at December 31, 2010
  $ 60,975  
Reduction for tax positions of current period
    (887 )
Additions for tax positions of prior periods
    -  
Reduction for tax positions of prior periods
    -  
Reduction for settlement with taxing authority
    -  
Reduction for lapse of statute of limitations
    -  
Balance at March 31, 2011
  $ 60,088  
 
The federal income tax years that remain subject to examination by the IRS are 2001 through 2010.  The Louisiana state income tax years that remain subject to examination by the Louisiana Department of Revenue are 2001 through 2010.  In December 2010 and February 2011, Cleco deposited $52.2 million and $8.2 million of funds, respectively, with the IRS associated with the years currently under audit.  
Cleco is currently under audit by the IRS which has proposed adjustments to taxes for various issues, including but not limited to, depreciable tax lives, bonus depreciation, deductible storm costs, research and experimentation costs, and repair allowance deductions.  Cleco estimates that it is reasonably possible that the balance of unrecognized tax benefits as of March 31, 2011, could decrease by a maximum of $63.6 million in the next 12 months as a result of reaching a settlement with the IRS.  The settlement could involve the payment of additional taxes, the adjustment of deferred taxes, and/or the recognition of tax benefits, which may have an effect on Cleco’s effective tax rate.
 
Note 8 — Disclosures about Segments


Cleco’s reportable segments are based on its method of internal reporting, which disaggregates business units by first-tier subsidiary.  Cleco’s reportable segments are Cleco Power and Midstream.  The reconciling items in the following tables consist of the holding company, a shared services subsidiary,
 
 
27

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
two transmission interconnection facilities, and an investment subsidiary.  
Each reportable segment engages in business activities from which it earns revenue and incurs expenses.  Segment managers report periodically to Cleco’s Chief Executive Officer (the chief operating decision-maker) with discrete financial information and, at least quarterly, present discrete financial information to Cleco Corporation’s Board of Directors.  Each reportable segment prepared budgets for 2011 that were presented to and approved by Cleco Corporation’s Board of Directors.  
The financial results of Cleco’s segments are presented on an accrual basis.  Management evaluates the performance of its segments and allocates resources to them based on segment profit and the requirements to implement new strategic initiatives and projects to meet current business objectives.  Material intercompany transactions occur on a regular basis.  These intercompany transactions relate primarily to joint and common administrative support services provided by Support Group.

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MARCH 31,
   
CLECO
         
RECONCILING
             
2011 (THOUSANDS)
 
POWER
   
MIDSTREAM
   
ITEMS
   
ELIMINATIONS
   
CONSOLIDATED
 
Revenue
                             
Electric operations
  $ 238,468     $ -     $ -     $ -     $ 238,468  
Tolling operations
    -       2,781       -       -       2,781  
Other operations
    12,243       1       485       (1 )     12,728  
Electric customer credits
    (434 )     -       -       -       (434 )
Affiliate revenue
    -       33       114       -       147  
Intercompany revenue
    346       -       10,907       (11,253 )     -  
Operating revenue
  $ 250,623     $ 2,815     $ 11,506     $ (11,254 )   $ 253,690  
Depreciation expense
  $ 27,401     $ 1,456     $ 241     $ -     $ 29,098  
Interest charges
  $ 24,402     $ 583     $ 1,567     $ 62     $ 26,614  
Interest income
  $ 113     $ 1     $ (60 )   $ 61     $ 115  
Equity income (loss) from investees
  $ -     $ 612     $ (1 )   $ -     $ 611  
Federal and state income tax expense (benefit)
  $ 14,400     $ (683 )   $ (1,522 )   $ -     $ 12,195  
Segment profit (loss) (1)
  $ 30,030     $ (1,097 )   $ 83     $ -     $ 29,016  
Additions to long-lived assets
  $ 40,729     $ 1,006     $ 60     $ -     $ 41,795  
Equity investment in investees
  $ 13,073     $ 74,261     $ 10     $ (1 )   $ 87,343  
Total segment assets
  $ 3,693,563     $ 316,637     $ 377,769     $ (330,058 )   $ 4,057,911  
(1) Reconciliation of segment profit to consolidated profit:
 
Segment profit
                    $ 29,016          
   
Unallocated items:
                         
   
Preferred dividends
requirements, net of tax
            12          
   
Net income applicable to common stock
    $ 29,004          

   
CLECO
         
RECONCILING
             
2010 (THOUSANDS)
 
POWER
   
MIDSTREAM
   
ITEMS
   
ELIMINATIONS
   
CONSOLIDATED
 
Revenue
                             
Electric operations
  $ 252,798     $ -     $ -     $ -     $ 252,798  
Tolling operations
    -       7,464       -       -       7,464  
Other operations
    10,386       1       490       (1 )     10,876  
Affiliate revenue
    -       905       244       -       1,149  
Intercompany revenue
    343       -       11,239       (11,582 )     -  
Operating revenue
  $ 263,527     $ 8,370     $ 11,973     $ (11,583 )   $ 272,287  
Depreciation expense
  $ 22,647     $ 1,443     $ 164     $ (1 )   $ 24,253  
Interest charges
  $ 18,743     $ 3,432     $ 846     $ (586 )   $ 22,435  
Interest income
  $ 158     $ -     $ 590     $ (586 )   $ 162  
Equity income from investees
  $ -     $ 37,846     $ 1     $ -     $ 37,847  
Gain on toll settlement
  $ -     $ 148,402     $ -     $ -     $ 148,402  
Federal and state income tax expense (benefit)
  $ 12,495     $ 71,388     $ (4,017 )   $ -     $ 79,866  
Segment profit (1)
  $ 32,160     $ 114,010     $ 3,800     $ -     $ 149,970  
Additions to long-lived assets
  $ 329,555     $ 547     $ 691     $ -     $ 330,793  
Equity investment in investees (2)
  $ 13,073     $ 73,648     $ 11     $ -     $ 86,732  
Total segment assets (2)
  $ 3,795,205     $ 316,165     $ 401,663     $ (351,623 )   $ 4,161,410  
(1) Reconciliation of segment profit to consolidated profit:
 
Segment profit
                    $ 149,970          
(2) Balances as of December 31, 2010
 
Unallocated items:
                         
   
Preferred dividends
requirements, net of tax
              12          
   
Net income applicable to common stock
    $ 149,958          
 


 
28

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
Note 9 — Electric Customer Credits

Beginning in 2010, the amount of Cleco Power’s yearly retail earnings is subject to the terms of a FRP established by the LPSC.  The new rates and the FRP became effective upon commencement of commercial operations at Madison Unit 3 on February 12, 2010.  The 2010 FRP establishes a target return on equity and requires all or a portion of regulated earnings for each yearly review period above the targeted regulatory rate of return on equity to be credited to Cleco Power’s customers. The 2010 FRP allows Cleco Power the opportunity to earn a target return on equity of 10.7%, including returning to retail customers 60% of retail earnings between 11.3% and 12.3% and all retail earnings over 12.3%. The amount of credits due customers, if any, is determined by Cleco Power and the LPSC annually. The 2010 FRP established that Cleco Power file monitoring reports for both the 12 months ended June 30, 2010, and September 30, 2010, on or before October 31, 2010, and January 31, 2011, respectively. Beginning in 2011, Cleco Power will file annual monitoring reports no later than October 31 for the 12-month period ending June 30.
On October 29, 2010, Cleco Power filed its report for the 12 months ended June 30, 2010, which indicated that no refund was due for this period.  On January 28, 2011, Cleco Power filed its report for the 12 months ended September 30, 2010, which indicated that Cleco Power’s retail earnings exceeded the refund threshold of 11.3%, but were less than 12.3%.  The ultimate amount of any customer refund is subject to LPSC Staff review and the closure of such review.  Credits are typically included on customers’ bills the following summer, but the timing of the refunds is ultimately at the discretion of the LPSC.
Cleco Power’s Condensed Consolidated Balance Sheets at March 31, 2011, and December 31, 2010, reflect the following accruals for estimated electric customer credits relating to the 12-month period ended September 30, 2010, and through the 12-month period ending June 30, 2011.

(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Provision of rate refund
  $ 10,032     $ 9,598  
Total customer credits
  $ 10,032     $ 9,598  

Note 10 — Variable Interest Entities

Cleco reports its investments in VIEs in accordance with the authoritative guidance.  Cleco Corporation and Cleco Power report the investment in Oxbow on the equity method of accounting.  At March 31, 2011, Cleco Corporation reported the investment in Cajun on the equity method of accounting.  Under the equity method, the assets and liabilities of these entities are reported as equity investment in investees on Cleco Corporation’s and Cleco Power’s Condensed Consolidated Balance Sheets.  The revenue and expenses (excluding income taxes) of these entities are netted and reported as equity income or loss from investees on Cleco Corporation’s and Cleco Power’s Condensed Consolidated Statements of Income.
Equity investment in investees at March 31, 2011, represented primarily Midstream’s $74.3 million investment in Cajun and Cleco Power’s $13.1 million investment in Oxbow.  Equity investments which are less than 100% owned by Cleco Innovations LLC represented less than $0.1 million of the total balance.
The following table presents the equity income (loss) from each investment accounted for using the equity method.  

   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
Cajun
  $ 612     $ 37,846  
Subsidiaries less than 100% owned by Cleco Innovations
    (1 )     1  
Total equity income
  $ 611     $ 37,847  
 
Cajun
In February 2009, Cleco Power announced that it had chosen the acquisition of Acadia Unit 1 as the lowest bid in its 2007 long-term RFP for capacity beginning in 2010.  Beginning in January 2010, Acadia operated the plant and served Cleco Power under a short-term tolling agreement covering Acadia Unit 1.  In February 2010, Cleco Power acquired Acadia Unit 1 and half of Acadia Power Station’s related common facilities and the tolling agreement was terminated.  In conjunction with this transaction, Acadia became 100% owned by Cajun, which at March 31, 2011, was 50% owned by APH and 50% owned by third parties.  For additional information regarding the Acadia Unit 1 transaction, see Note 15 — “Acadia Unit 1 Transaction.”
At March 31, 2011, APH was not the primary beneficiary, and Cajun was accounted for as an equity method investment.  Cleco has determined that APH is not the primary beneficiary because it shares the power to control Cajun’s significant activities with third parties.  Cleco’s assessment of its maximum exposure to loss related to Cajun at March 31, 2011, consisted of its equity investment of $74.3 million.  The table below presents the components of Midstream’s equity investment in Cajun.

INCEPTION TO DATE (THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Contributed assets (cash and land)
  $ 284,456     $ 284,456  
Net income
    182,661       182,048  
Impairment of investment
    (45,847 )     (45,847 )
Capitalized interest and other
    19,722       19,722  
Less:  non-cash distribution
    230,267       230,267  
Less:  cash distributions
    136,464       136,464  
Total equity investment in investee
  $ 74,261     $ 73,648  
 
The following table compares the carrying amount of Cajun’s assets and liabilities with Cleco’s maximum exposure to loss related to its investment in Cajun.

(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Cajun’s net assets/liabilities
  $ 200,772     $ 199,547  
Midstream’s 50% equity
  $ 100,386     $ 99,773  
Impairment of investment
    (45,847 )     (45,847 )
Capitalized interest
    19,722       19,722  
Cleco’s maximum exposure to loss
  $ 74,261     $ 73,648  
 
 
 
29

 
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CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
The following tables contain summarized financial information for Cajun.

(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Current assets
  $ 8,823     $ 7,133  
Property, plant and equipment, net
    203,767       203,793  
Total assets
  $ 212,590     $ 210,926  
Current liabilities
  $ 3,261     $ 1,950  
Other liabilities
    8,557       9,429  
Partners’ capital
    200,772       199,547  
Total liabilities and partners’ capital
  $ 212,590     $ 210,926  

   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
Operating revenue
  $ 5,177     $ 3,764  
Operating expenses
    4,824       10,163  
Gain on sales of assets
    -       82,039  
Other income
    872       52  
Income before taxes
  $ 1,225     $ 75,692  
 
Other liabilities at March 31, 2011, represented indemnification liabilities related to the Cleco Power transaction.  For additional information on Acadia’s indemnification liability, see Note 11 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Disclosures about Guarantees.”
Income tax expenses recorded on APH’s financial statements related to Midstream’s 50% ownership interest in Cajun were $0.3 million and $14.3 million for the three months ended March 31, 2011, and 2010, respectively.  
In October 2009, Acadia and Entergy Louisiana announced that definitive agreements had been executed whereby Entergy Louisiana would acquire Acadia Unit 2.  At March 31, 2011, the carrying value of this unit and the related material and supplies inventory were considered assets held for sale on Acadia’s financial statements.  At March 31, 2011, no gain or loss was recorded, as the fair value less the costs to sell was greater than the carrying value, and the transaction had not yet been completed.  On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 to Entergy Louisiana for approximately $300.0 million.  Following the disposition, Acadia no longer owns any materials and supply inventory, property, plant and equipment, or land.  Ongoing operations are minimal, relating only to the previously established receivables and payables and servicing of indemnities.  Cleco Power continues to operate both units at the Acadia Power Station.  For additional information on the Acadia Unit 2 transaction, see Note 16 — “Subsequent Event.”
In connection with the Entergy Louisiana transaction, APH has agreed to indemnify the third party owners of Cajun and their affiliates against their share of Acadia’s contingent obligations related to the transaction.  For additional information on the Entergy Louisiana indemnification, see Note 11 — “Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Disclosures about Guarantees.”
 
Oxbow
Oxbow is owned 50% by Cleco Power and 50% by SWEPCO and is accounted for as an equity method investment.  Cleco Power is not the primary beneficiary because it shares the power to control Oxbow’s significant activities with SWEPCO.  Cleco’s current assessment of its maximum exposure to loss related to Oxbow at March 31, 2011, consisted of its equity investment of $13.1 million.  The table below presents the components of Cleco Power’s equity investment in Oxbow.

INCEPTION TO DATE (THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Purchase price
  $ 12,873     $ 12,873  
Cash contributions
    200       200  
Total equity investment in investee
  $ 13,073     $ 13,073  
 
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 MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Oxbow’s net assets/liabilities
  $ 26,146     $ 26,146  
Cleco Power’s 50% equity
  $ 13,073     $ 13,073  
Cleco’s maximum exposure to loss
  $ 13,073     $ 13,073  
 
The following tables contain summarized financial information for Oxbow.

(THOUSANDS)
 
AT MARCH 31, 2011
   
AT DECEMBER 31, 2010
 
Current assets
  $ 607     $ 583  
Property, plant and equipment, net
    23,557       23,597  
Other assets
    2,156       2,141  
Total assets
  $ 26,320     $ 26,321  
Current liabilities
  $ 174     $ 175  
Partners’ capital
    26,146       26,146  
Total liabilities and partners’ capital
  $ 26,320     $ 26,321  

   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
 
Operating revenue
  $ 205     $ 94  
Operating expenses
    205       94  
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.  The special notice requested that Cleco Corporation and Cleco Power, along with many other listed potentially responsible parties, 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
 
 
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CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
has identified Cleco as one of many companies sending PCB wastes for disposal to the site.  The Devil’s Swamp Lake site has been proposed to be added to the National Priorities List (NPL) based on the release of PCBs to fisheries and wetlands located on the site.  The EPA has yet to make a final determination on whether to add Devil’s Swamp Lake site to the NPL.  The PRPs began discussing a potential proposal to the EPA in February 2008.  Negotiations among the PRPs and the EPA are ongoing in regard to the RI/FS for the Devil’s Swamp Lake site, with little progress having been made since February 2008.  Since this investigation is in the preliminary stages, management is unable to determine whether the costs associated with possible remediation of the facility site will have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.
 
Discrimination Complaint
On December 11, 2009, a complaint was filed in the U.S. District Court for the Western District of Louisiana (the Court) on behalf of eight current employees and four former employees alleging that Cleco discriminated against each of them on the basis of race.  Each is seeking various remedies provided under applicable statutes prohibiting racial discrimination in the workplace, and together, the plaintiffs seek monetary compensation exceeding $35.0 million.  On July 29, 2010, the plaintiffs moved to add an additional current employee alleging that Cleco had discriminated on the basis of race.  The plaintiff seeks compensation of no less than $2.5 million and became the thirteenth plaintiff.  On April 13, 2011, Cleco entered into a settlement with one of the current employees which resulted in a dismissal of one of the thirteen cases with prejudice.  Cleco is awaiting the Court’s decision as to summary judgment motions that it has submitted with respect to each of the other twelve cases.  
On September 23, 2010, the New Orleans Field Office of the U.S. Equal Employment Opportunity Commission (EEOC) issued its determination that there is reason to believe that violations of Title VII of the Civil Rights Act of 1964 had occurred at one of Cleco’s training facilities on October 5, 2007.  In its initial determination, the EEOC suggested that Cleco pay the charging party $0.1 million in satisfaction of any compensatory or punitive damages.  Under EEOC procedures, Cleco pursued conciliation efforts to resolve the charge which resulted in a complete settlement with the charging party and the EEOC.  No trial in this matter is currently scheduled.  Management believes these lawsuits will not have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.
 
City of Opelousas
On March 9, 2010, a complaint was filed in the 27th Judicial District Court of St. Landry Parish, State of Louisiana, on behalf of three Cleco Power customers in Opelousas, Louisiana.  The complaint alleges that Cleco Power overcharged the plaintiffs by applying to customers in Opelousas the same retail rates as Cleco Power applies to all of its retail customers.  The plaintiffs allege that Cleco Power should have established, solely for customers in Opelousas, retail rates that are separate and distinct from the retail rates that apply to other customers of Cleco Power and that Cleco Power should not collect from customers in Opelousas the storm surcharge approved by the LPSC following Hurricanes Katrina and Rita.  Cleco Power currently operates in Opelousas pursuant to a franchise granted to Cleco Power by the City of Opelousas in 1986 and an operating and franchise agreement dated May 14, 1991, pursuant to which Cleco Power operates its own electric facilities and leases and operates electric facilities owned by the City of Opelousas.  In April 2010, Cleco Power filed a petition with the LPSC appealing to its expertise in declaring that the ratepayers of Opelousas have been properly charged the rates that are applicable to Cleco Power’s retail customers and that no overcharges have been collected.  In addition, Cleco Power removed the purported class action lawsuit filed on behalf of Opelousas electric customers from the state court to the U.S. District Court for the Western District of Louisiana in April 2010, so that it could be properly addressed under the terms of the Class Action Fairness Act.  On May 11, 2010, a second class action lawsuit was filed in the 27th Judicial District Court of St. Landry Parish, State of Louisiana, repeating the allegations of the first complaint, which was submitted on behalf of a number of Opelousas residents.  Cleco Power has responded in the same manner as with the first class action lawsuit.  On September 29, 2010, the federal court remanded both cases to the state court in which they were originally filed for further proceedings.  On January 21, 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.  On February 7, 2011, the administrative law judge in the LPSC proceeding ruled that the commission has jurisdiction to decide the claims raised by the class action plaintiffs.  Both Cleco and the LPSC Staff appealed this ruling to the Third Circuit Court of Appeals for the State of Louisiana, and await a decision by such court.  Management believes that these lawsuits will not have a material adverse effect on the Registrants’ financial condition, results of operations, or 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.  Some of these proceedings, such as the fuel review and environmental issues, could involve substantial amounts.  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 necessary, provides accruals for probable liabilities on the eventual disposition of these matters.  As of March 31, 2011, approximately $7.9 million was accrued for these various matters.  Management believes the disposition of these matters
 
 
31

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
will not have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.
 
Off-Balance Sheet Commitments
Cleco Corporation and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Corporation’s subsidiaries and equity investees (affiliates).  Cleco Corporation and Cleco Power also have agreed to contractual terms that require them to pay third parties if certain triggering events occur.  These contractual terms generally are defined as guarantees in the authoritative guidance.  
Cleco Corporation entered into these off-balance sheet commitments in order to entice desired counterparties to contract with its affiliates by providing some measure of credit assurance to the counterparty in the event Cleco’s affiliates do not fulfill certain contractual obligations.  If Cleco Corporation had not provided the off-balance sheet commitments, the desired counterparties may not have contracted with Cleco’s affiliates, or may have contracted with them at terms less favorable to its affiliates.
The off-balance sheet commitments are not recognized on Cleco Corporation’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.  At March 31, 2011, these off-balance sheet commitments reduced available borrowings by $15.0 million.  Cleco’s off-balance sheet commitments as of March 31, 2011, 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 MARCH 31, 2011
 
   
FACE
         
NET
 
(THOUSANDS)
 
AMOUNT
   
REDUCTIONS
   
AMOUNT
 
Cleco Corporation
                 
Guarantee issued to Entergy Louisiana and Entergy Gulf States for performance obligations of Perryville
  $ 177,400     $ 135,000     $ 42,400  
Guarantee issued to Entergy Mississippi on behalf of Attala
    500       -       500  
Guarantee issued to Cleco Power on behalf of Acadia*
    6,750       2,472       4,278  
Guarantee issued to Entergy Louisiana on behalf of Acadia
    10,000       -       10,000  
Cleco Power
                       
Obligations under standby letter of credit issued to the Louisiana Department of Labor
    3,725       -       3,725  
Total
  $ 198,375     $ 137,472     $ 60,903  
*Represents APH’s 50% share
 
 
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.  As of March 31, 2011, the aggregate guarantee of $177.4 million was limited to $42.4 million due to the performance of some of the underlying obligations that were guaranteed.  Management believes it is unlikely that Cleco Corporation will have any other liabilities which would give rise to indemnity claims.  The discounted probability-weighted liability under the guarantees and indemnifications recognized on the balance sheets as of March 31, 2011, was $0.2 million.
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.
Acadia provided limited guarantees and indemnifications to Cleco Power under the Master Reorganization and Redemption Agreement related to the acquisition of Acadia Unit 1 and half of Acadia Power Station’s related common facilities in February 2010.  In connection with this transaction, Acadia became 100% owned by Cajun, which at March 31, 2011 was 50% owned by APH and 50% owned by third parties.  In relation to the Cleco Power transaction, Acadia agreed to indemnify Cleco Power and its affiliates against 100% of Acadia’s contingent obligations.  As of March 31, 2011, APH’s share of this guarantee, through its 50% ownership in Cajun, has been reduced to $4.3 million, primarily due to the contractual expiration of the underlying indemnifications and management’s assumptions about the decreasing probability of a payment due to the passage of time.
Acadia and Entergy Services entered into an amended capacity sale and fuel conversion services agreement on June 30, 2010, with an effective date of October 1, 2010.  In conjunction with the agreement, Cleco Corporation provided to Entergy Louisiana a limited guarantee, in an amount not to exceed $10.0 million, for certain performance obligations by Acadia under the agreement.  On April 29, 2011, the agreement and the related guarantee terminated as a result of the Acadia Unit 2 sale transaction.  For additional information regarding this transaction, see Note 16 — “Subsequent Event.”
The State of Louisiana allows employers of certain financial net worth to self-insure their workers’ compensation benefits.  Cleco Power has a certificate of self-insurance from the Louisiana Office of Workers’ Compensation and is required to post a $3.7 million letter of credit, an amount equal to 110% of the average losses over the previous three years, as surety.
 
Disclosures about Guarantees
In February 2010, Cleco Power acquired Acadia Unit 1 and half of Acadia Power Station’s related common facilities. Acadia provided limited guarantees and indemnifications to Cleco Power under the Master Reorganization and Redemption Agreement.  Acadia recorded an indemnification liability and a corresponding reduction of the gain of $13.5 million which represents the fair value of these indemnifications.  In a related agreement, APH agreed to accept 50% of Acadia’s
 
 
32

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
indemnification liability that would be held by the third parties who indirectly own 50% of Acadia in return for $6.8 million received from the third parties.  The $6.8 million was recorded as an indemnification liability by APH.  Events that would require payments to Cleco Power pursuant to the indemnity include, but are not limited to:
 
§  
Environmental costs that were caused by events occurring before the closing of the transaction;
§  
Claims against Cleco Power for liabilities retained by Acadia;
§  
Certain conditions of Acadia Unit 1 that were discovered prior to September 30, 2010; and
§  
Breach of fundamental representations of Acadia, such as legal existence, ownership of Acadia Unit 1 and valid authorization to dispose of Acadia Unit 1.
 
Acadia and APH will be released from the underlying liabilities either through expiration of the contractual life or through a reduction in the probability of a claim arising.  The indemnification obligation is expected to have a term of approximately three years, which reflects both contractual expiration of the underlying indemnifications and management’s assumptions about the decreasing probability of a payment due to the passage of time.  After the three-year period, a residual value of less than $0.1 million will remain.  At March 31, 2011, APH had an indemnification liability of $4.3 million, which represents the risk of payment.
As part of the Lignite Mining Agreement amended in 2009, Cleco Power and SWEPCO, joint owners of Dolet Hills, have agreed to pay the lignite miner’s loan and lease principal obligations when due, if the lignite miner does not have sufficient funds or credit to pay.  Any amounts paid on behalf of the miner would be credited by the lignite miner against the next invoice for lignite delivered.  At March 31, 2011, 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.
The following table summarizes the expected termination dates of the off-balance sheet commitments and on-balance sheet guarantees discussed above:

                     
AT MARCH 31, 2011
 
         
AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
 
   
NET
                     
MORE
 
   
AMOUNT
   
LESS THAN
               
THAN
 
(THOUSANDS)
 
COMMITTED
   
ONE YEAR
   
1-3 YEARS
   
3-5 YEARS
   
5 YEARS
 
Off-balance sheet commitments
  $ 60,903     $ 13,725     $ 4,278     $ -     $ 42,900  
On-balance sheet guarantees
    8,060       -       4,279       -       3,781  
Total
  $ 68,963     $ 13,725     $ 8,557     $ -     $ 46,681  
 
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.
 
Other Commitments
 
Madison Unit 3
In August 2005, Cleco Power entered into an EPC contract with Shaw to construct Madison Unit 3.  Cleco Power began construction of Madison Unit 3 in May 2006.  In May 2006, Cleco Power and Shaw entered into an Amended EPC Contract, which contract has subsequently been amended by the parties.  The project achieved commercial operations on February 12, 2010, whereby Cleco Power accepted care, custody, and control of the unit.  Shaw has not reached project completion under the contract, as various performance tests, the reliability test and specified boiler performance criteria have not been met.  Shaw must correct various identified items, complete various performance guarantee tests, meet a 30-day reliability performance test, and correct various warranty issues.  Cleco Power and Shaw have submitted various claims, relating to the Amended EPC Contract, to arbitration.  On April 30, 2010, Shaw filed a demand for arbitration asserting claims of $32.0 million including impacts due to the 2008 hurricane force majeure, alleged excess fuel moisture, intake water quality and a river embankment slope failure, and the associated recovery of schedule related liquidated damages withheld by Cleco Power.  In May 2010, Cleco Power issued to
 
 
33

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
Shaw a notice of default relating to Shaw’s inability to meet certain material obligations under the Amended EPC Contract.  Furthermore, as a result of Shaw filing the demand for arbitration, certain claims exceeded a $1.0 million threshold, triggering an unwind of certain fuel related matters included in a prior settlement between the parties, Amendment No. 4, and Cleco demanded an associated payment of $19.0 million.  In February 2011, Cleco drew on the Shaw letter of credit in an amount of $19.0 million for amounts relating to the unwind.  Shaw has amended its demand for arbitration to contest the unwind, and is seeking recovery of such amounts in the on-going arbitration proceedings.  Under the arbitration proceedings, Cleco has also filed compulsory counterclaims for liquidated damages associated with Shaw’s inability to meet various guarantees in the amount of $94.0 million, and up to $320.0 million in warranty claims associated with boiler performance burning petroleum coke.  All of these matters will be resolved by decision of the arbitrator in accordance with the terms of the Amended EPC Contract.  The arbitration process is expected to be completed during the third quarter of 2011.  The Registrants do not believe the resolution of the claims discussed above will have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.
 
Acadia Transactions
In February 2009, Cleco Power announced that it had chosen the acquisition of Acadia Unit 1 as the lowest bid in its 2007 long-term RFP for capacity beginning in 2010.  Beginning in January 2010, Acadia operated the plant and served Cleco Power under a short-term tolling agreement covering Acadia Unit 1.  In February 2010, the transaction closed and the tolling agreement was terminated.  For additional information regarding the Cleco Power transaction, see Note 15 — “Acadia Unit 1 Transaction.”
In October 2009, Acadia and Entergy Louisiana announced that definitive agreements had been executed whereby Entergy Louisiana would acquire Acadia Unit 2.  An interim power purchase agreement between Acadia and Entergy Louisiana began in June 2010.  Effective October 1, 2010, this power purchase agreement was subject to a $10.0 million guarantee by Cleco Corporation.  For additional information regarding this guarantee, please refer to “— Off-Balance Sheet Commitments” above.  On April 29, 2011, the transaction closed and the tolling agreement terminated.  Cleco Power will continue to operate both units at the Acadia Power Station.  In connection with this transaction and in exchange for reasonable consideration, APH has indemnified the third-party owners of Cajun and their affiliates against 100% of Acadia’s liabilities and other obligations related to the Entergy Louisiana transaction.  For additional information on the Acadia Unit 2 sale transaction, see Note 16 — “Subsequent Event.”
 
Other
Cleco has accrued for liabilities 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.  
 
Evangeline Tolling Agreement
JPMorgan Chase & Co. guarantees JPMVEC’s obligations under the Evangeline 2010 Tolling Agreement.  For additional information regarding this tolling agreement, see Note 14 — “Evangeline Transactions.”
 
Other
Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows.  Market conditions during the past few years have limited the availability and have increased the costs of capital for many companies.  The inability to raise capital on favorable terms could negatively affect Cleco Corporation’s and Cleco Power’s ability to maintain and expand their businesses.  After assessing the current operating performance, liquidity, and credit ratings of Cleco, management believes that Cleco will have access to the capital markets at prevailing market rates for companies with comparable credit ratings.  If Cleco Corporation’s credit ratings were to be downgraded by Moody’s and Standard & Poor’s, Cleco Corporation would be required to pay additional fees and higher interest rates under its bank credit and other debt agreements.
Changes in the regulatory environment or market forces could cause Cleco to determine its assets have suffered an other-than-temporary decline in value, whereby an impairment would be required to be taken and Cleco’s financial condition could be materially adversely affected.
 
Cleco Power
Cleco Power supplies the majority of its customers’ electric power requirements from its own generation facilities.  In addition to power obtained from power purchase agreements, Cleco Power purchases power from other utilities and marketers to supplement its generation at times of relatively high demand or when the purchase price of power is less than its own cost of generation.  Due to its location on the transmission grid, Cleco Power relies on two main suppliers of electric transmission when accessing external power markets.  At times, constraints limit the amount of purchased power these transmission providers can deliver into Cleco Power’s service territory.
Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows.  Market conditions during the past few years have limited the availability and have increased the costs of capital for many companies.  The inability to raise capital on favorable terms could negatively affect Cleco Power’s ability to maintain and expand its businesses.  After
 
 
34

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
assessing the current operating performance, liquidity, and credit ratings of Cleco Power, management believes that Cleco Power will have access to the capital markets at prevailing market rates for companies with comparable credit ratings.  Cleco Power pays fees and interest under its bank credit agreements based on the highest rating held.  If Cleco Power’s credit ratings were to be downgraded by Moody’s and Standard & Poor’s, Cleco Power would be required to pay additional fees and higher interest rates under its bank credit agreements.  Cleco Power’s collateral for derivatives is based on the lowest rating held.  If Cleco Power’s credit ratings were to be downgraded by Moody’s or Standard & Poor’s, Cleco Power would be required to pay additional collateral for derivatives.
In August 2005, Cleco Power entered into an EPC contract with Shaw to construct Madison Unit 3.  In May 2006, Cleco Power and Shaw entered into an Amended EPC Contract.  Under the terms of the Amended EPC Contract until final acceptance of Madison Unit 3, in the event Cleco Power does not maintain a senior unsecured credit rating of either: (i) Baa3 or better from Moody’s or (ii) BBB- or better from Standard & Poor’s, Cleco Power will be required to provide a letter of credit to Shaw in the amount of $20.0 million.  In the event of further downgrade to both of its credit ratings to:  (i) Ba2 or below from Moody’s, and (ii) BB or below from Standard & Poor’s, Cleco Power will be required to provide an additional $15.0 million letter of credit to Shaw.
 
Note 12 — LPSC Fuel Audit

The LPSC Fuel Adjustment Clause General Order issued November 6, 1997, in Docket No. U-21497 provides that an audit of fuel adjustment clause filings will be performed not less than every other year.  Cleco Power’s last fuel audit was for the years 2001 and 2002.  Cleco Power currently has fuel adjustment clause filings for 2003 through 2010 subject to audit.  In March 2009, the LPSC proceeded with the audit of fuel adjustment clause filings for the years 2003 through 2008.  The total amount of fuel expenses included in the audit is approximately $3.2 billion.  Cleco Power has responded to data requests from the LPSC.  These responses are currently under review by the LPSC.  Management is unable to determine the outcome of this audit.  However, if a disallowance of fuel costs is ordered resulting in a refund, any such refund could have a material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.
 
Note 13 — Affiliate Transactions

Cleco has affiliate balances that were not eliminated as of March 31, 2011.  The balances were not eliminated due to the use of the equity method of accounting for Acadia.  For information on the Acadia equity investments, see Note 10 — “Variable Interest Entities.”  At March 31, 2011, the receivable from Acadia was $1.4 million, and the payable to Acadia was less than $0.1 million.
Cleco Power has affiliate balances that are payable to or due from its affiliates.  At March 31, 2011, the payable to Cleco Corporation was $11.6 million, the payable to Support Group was $5.7 million, and the payable to other affiliates was less than $0.1 million.  Also, at March 31, 2011, the receivable from Support Group was $1.9 million, the receivable from Acadia was $1.3 million, the receivable from Cleco Corporation was $0.3 million, and the receivable from other affiliates was $0.1 million.
 
Note 14 — Evangeline Transactions

On February 22, 2010, Evangeline and JPMVEC entered into the Evangeline Restructuring Agreement whereby the parties agreed to terminate the existing Evangeline Tolling Agreement and entered into the Evangeline 2010 Tolling Agreement, effective March 1, 2010.  The other significant terms of the Evangeline Restructuring Agreement are:
 
§  
The tolling agreement is a market-based tolling agreement, for Coughlin Units 6 and 7, ending December 31, 2011, with an option for JPMVEC to extend the term through December 31, 2012.  The agreement also gives Evangeline the right to terminate its Coughlin Unit 6 obligations prior to the expiration of the term.  JPMVEC did not exercise the option to extend the tolling agreement;
§  
$126.6 million of Evangeline’s 8.82% Senior Secured bonds due 2019, owned by JPMVEC, were transferred to Evangeline and subsequently retired; and $5.3 million of accrued interest associated with the bonds transferred to Evangeline was eliminated;
§  
JPMVEC paid Evangeline $56.7 million;
§  
JPMVEC returned Cleco Corporation’s $15.0 million letter of credit issued under the Evangeline Tolling Agreement and the letter of credit was cancelled; and
§  
Evangeline recorded a gain of $148.4 million.
 
The termination of the Evangeline Tolling Agreement was considered a termination of an operating lease and a triggering event requiring an asset impairment analysis.  Management made assumptions about expected future cash flows, long-term interest rates, estimates about the probability of the occurrence of future events, and estimates of market values of assets without a readily observable market price.  An impairment charge was not recorded since the undiscounted expected future net cash flows exceeded the carrying value of Evangeline’s property, plant and equipment.  Due to the lack of a long-term agreement, the expected future net cash flows of Evangeline are subject to an increased potential for variability as compared to prior years.  Consequently, future impairment tests could occur more frequently and might result in an impairment charge.
Under the terms of the Evangeline Restructuring Agreement, Evangeline issued an irrevocable redemption notice to redeem the remaining $35.2 million of 8.82% Senior Secured bonds outstanding pursuant to their terms on February 25, 2010, and paid the debtholders $1.5 million of accrued interest and a $10.2 million make-whole payment.  As a result of the debt retirement, Evangeline expensed $2.1 million in unamortized debt issuance costs associated with the Evangeline bonds.  The Evangeline bonds were non-recourse to
 
 
35

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
Cleco Corporation and redemption of the bonds was permitted under Cleco Corporation’s revolving credit facility.  Upon the redemption of the bonds, $30.1 million of restricted cash was released to Evangeline.  
The impacts of these transactions are reflected in the Midstream segment, which includes Evangeline.  In accordance with the authoritative guidance, effective January 1, 2010, the financial results for Evangeline are no longer presented as equity income (loss), but presented in the corresponding line items in the consolidated financials of Midstream.
 
Note 15 — Acadia Unit 1 Transaction

In February 2010, Cleco Power completed the acquisition of Acadia Unit 1 and half of Acadia Power Station’s related common facilities.  The significant terms of the transaction were:
 
§  
Cleco Power acquired Acadia Unit 1 and half of the common facilities for $304.0 million;
§  
Cleco Power recognized $78.4 million of deferred taxes on the transaction.  For additional information on the deferred taxes, see Note 7 — “Income Taxes;”
§  
Acadia recognized a gain of $82.0 million;
§  
APH received $6.8 million from third parties in return for APH’s indemnification against the third parties’ 50% share of Acadia’s liabilities and other obligations related to the Cleco Power transaction;
§  
Cleco Power and the parties executed the definitive agreements in 2009, and received LPSC and FERC approvals for the transaction in January 2010 and February 2010, respectively; and
§  
Cleco Power owns and operates Acadia Unit 1.  Prior to April 29, 2011, Cleco Power operated Acadia Unit 2 on behalf of Acadia.  On April 29, 2011, the sale of Acadia Unit 2 to Entergy Louisiana closed.  Cleco Power now operates Acadia Unit 2 on behalf of Entergy Louisiana.  
 
Note 16 — Subsequent Event

On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 and half of Acadia Power Station’s related common facilities to Entergy Louisiana.  The significant terms of the transaction were:
 
§  
Entergy Louisiana acquired Acadia Unit 2 for approximately $300.0 million;
§  
In exchange for $10.9 million, APH indemnified the third party owners of Cajun and their affiliates against 50% of Acadia’s liabilities and other obligations related to the Acadia Unit 2 transaction;
§  
APH recognized a gain of approximately $60.0 million; and
§  
Cleco Power operates Acadia Unit 2 on behalf of Entergy Louisiana.

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

The following discussion and analysis should be read in combination with the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010, and Cleco Corporation and Cleco Power’s Condensed Consolidated Financial Statements contained in this Form 10-Q.  The information included therein is essential to understanding the following discussion and analysis.  Below is information concerning the consolidated results of operations of Cleco for the three months ended March 31, 2011, and March 31, 2010.
 
RESULTS OF OPERATIONS

 
Overview
Cleco is a regional energy services holding company that conducts substantially all of its business operations through its two primary subsidiaries:
 
§  
Cleco Power, an integrated electric utility services company regulated by the LPSC, FERC, and other regulators, which serves approximately 279,000 customers across Louisiana and also engages in energy management activities; and
§  
Midstream, a merchant energy company regulated by FERC, which owns Evangeline (which operates the Coughlin Power Station).  At March 31, 2011, Midstream also owned a 50 percent indirect interest in Acadia.  On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 to Entergy Louisiana.  For additional information, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 16 — Subsequent Event.”
 
Cleco Power
Many factors affect Cleco Power’s primary business of selling electricity.  These factors include the presence of a stable regulatory environment, which can impact cost recovery and return on equity, as well as the recovery of costs related to growing energy demand and rising fuel prices; the ability to increase energy sales while containing costs; and the ability to meet increasingly stringent regulatory and environmental standards.  Key initiatives that Cleco Power is currently working on include the Acadiana Load Pocket project and the AMI project.  Another key project, the Teche Unit 4 Blackstart project, was completed in April 2011.  A brief discussion of these projects is discussed below.
 
Acadiana Load Pocket Project
In September 2008, Cleco Power entered into an agreement with two other utilities to upgrade and expand interconnected transmission systems in south central Louisiana in an area known as the Acadiana Load Pocket.  The project received LPSC and SPP approval in February 2009.  Cleco Power’s initial portion of the estimated cost was approximately $150.0 million, including AFUDC.  Due to lower material and labor
 
 
36

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
costs than initially expected, Cleco Power’s estimated costs for its portion of the project has been reduced to $125.0 million, including AFUDC.  At March 31, 2011, Cleco Power had spent $67.5 million on the project and expects to incur an additional $30.7 million during 2011, including AFUDC.  The project is estimated to be 75% complete with the final completion date expected in 2012.  For additional information, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Regulatory Matters — Acadiana Load Pocket Project” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.  For information on the impact the Acadiana Load Pocket project is expected to have on base revenue, see “— Comparison of the Three Months Ended March 31, 2011, and 2010 — Cleco Power — Base.”
 
AMI Project
In May 2010, Cleco Power accepted the terms of a $20.0 million grant from the DOE under the DOE’s small-grant process to implement smart-grid technology for all of Cleco Power’s retail customers.  Cleco Power estimates the project will cost $73.0 million, with the DOE grant providing $20.0 million toward the project and Cleco Power providing the remaining $53.0 million.  The grant program is a part of the American Recovery and Reinvestment Act of 2009, an economic stimulus package passed by Congress in February 2009.  Smart-grid technology includes the installation of electric meters that enable two-way communication capabilities between a home or business and a utility company.  At March 31, 2011, Cleco Power had incurred $2.9 million in AMI costs, of which $1.2 million has been submitted to the DOE for reimbursement.  As of March 31, 2011, Cleco Power had received $0.8 million in payments from the DOE for the AMI project.  The project is expected to be completed in the second quarter of 2013.  For additional information, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Other Matters — AMI Project” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Teche Unit 4 Blackstart Project
In April 2011, Cleco Power completed the work on its project to improve its “blackstart” process (the return of its generation system to service in the event of a total shutdown) as the 33-MW gas turbine at Teche Power Station, which has been designated Teche Unit 4, was placed into commercial operation.  At March 31, 2011, Cleco Power had spent $27.7 million on the project and expects to incur an additional $3.6 million during the remainder of 2011.  For additional information, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Other Matters — Teche Unit 4 Blackstart Project” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Cleco Midstream
 
Evangeline
In March 2010, Evangeline restructured its tolling agreement with JPMVEC and shortened the expiration of the prior long-term agreement from 2020 to December 31, 2011 (with a JPMVEC option to extend one year).  JPMVEC did not exercise the option to extend the tolling agreement and as a result, Coughlin’s capacity will be available to Midstream beginning January 1, 2012.  Currently, Midstream is aggressively marketing Coughlin’s capacity for periods beginning on or after January 1, 2012, and is evaluating various options to optimize Coughlin’s value.
 
Acadia
In October 2009, Acadia and Entergy Louisiana executed definitive agreements whereby Entergy Louisiana would purchase Acadia Unit 2.  On April 29, 2011, Acadia completed its disposition of Acadia Unit 2 to Entergy Louisiana for approximately $300.0 million.  APH’s portion of the proceeds from the sale were used to repay Cleco Corporation’s $150.0 million bank term loan.  For additional information on the Acadia Unit 2 sale transaction, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 16 — Subsequent Event.”
 
Comparison of the Three Months Ended March 31, 2011, and 2010
 
Cleco Consolidated
         
FOR THE THREE MONTHS ENDED MARCH 31,
 
               
FAVORABLE/(UNFAVORABLE)
 
(THOUSANDS)
 
2011
   
2010
   
VARIANCE
   
CHANGE
 
Operating revenue, net
  $ 253,690     $ 272,287     $ (18,597 )     (6.8 )%
Operating expenses
    188,456       216,386       27,930       12.9  %
Operating income
  $ 65,234     $ 55,901     $ 9,333       16.7  %
Allowance for other funds used during construction
  $ 1,978     $ 9,805     $ (7,827 )     (79.8 )%
Equity income from investees
  $ 611     $ 37,847     $ (37,236 )     (98.4 )%
Gain on toll settlement
  $ -     $ 148,402     $ (148,402 )     -  
Interest charges
  $ 26,614     $ 22,435     $ (4,179 )     (18.6 )%
Federal and state income taxes
  $ 12,195     $ 79,866     $ 67,671       84.7  %
Net income applicable to common stock
  $ 29,004     $ 149,958     $ (120,954 )     (80.7 )%
 
Consolidated net income applicable to common stock decreased $121.0 million, or 80.7%, in the first quarter of 2011 compared to the first quarter of 2010 primarily due to the absence of the gains at Midstream related to the termination of the Evangeline Tolling Agreement and Acadia Unit 1 transaction.  Also contributing to the decrease was lower Cleco Power and corporate earnings.
Operating revenue, net decreased $18.6 million, or 6.8%, in the first quarter of 2011 compared to the first quarter of 2010 largely as a result of lower fuel cost recovery revenue at Cleco Power.
Operating expenses decreased $27.9 million, or 12.9%, in the first quarter of 2011 compared to the first quarter of 2010 primarily due to lower per unit costs of fuel used for electric generation and power purchased for utility customers.  Also
 
 
37

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
contributing to the decrease were lower volumes of power purchased for utility customers.
Allowance for other funds used during construction decreased $7.8 million, or 79.8%, in the first quarter of 2011 compared to the first quarter of 2010 primarily due to the cessation of AFUDC accruals related to the completion of construction activity at Madison Unit 3.  
Equity income from investees decreased $37.2 million, or 98.4%, in the first quarter of 2011 compared to the first quarter of 2010 primarily due to the absence of the gain from Cleco Power’s acquisition of Acadia Unit 1 and half of Acadia Power Station’s related common facilities from Acadia during the first quarter of 2010.  For additional information on Acadia, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 10 — Variable Interest Entities” and “Note 15 — Acadia Unit 1 Transaction.”  
Gain on toll settlement was $148.4 million in the first quarter of 2010 due to transactions related to the termination of the existing Evangeline Tolling Agreement and the execution of the Evangeline 2010 Tolling Agreement.  For additional information, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 14 — Evangeline Transactions.”  
Interest charges increased $4.2 million, or 18.6%, during the first quarter of 2011 compared to the first quarter of 2010 primarily due to higher interest charges at Cleco Power and higher corporate interest charges primarily related to a bank term loan executed during the first quarter of 2010.  Partially offsetting these increases was lower interest charges at Midstream.
Federal and state income taxes decreased $67.7 million, or 84.7%, during the first quarter of 2011 compared to the first quarter of 2010.  The decreases include $69.5 million for the change in pre-tax income excluding AFUDC equity, $1.9
million for a Medicare Part D adjustment resulting from new legislation enacted in 2010, and $0.9 million for other miscellaneous items.  These decreases were partially offset by $3.0 million for an adjustment in 2010 related to the implementation of the new retail rates approved by the LPSC and $1.6 million to record tax expense at the consolidated projected annual effective tax rate.
Results of operations for Cleco Power and Midstream are more fully described below.
 
Cleco Power
         
FOR THE THREE MONTHS ENDED MARCH 31,
 
               
FAVORABLE/(UNFAVORABLE)
 
(THOUSANDS)
 
2011
   
2010
   
VARIANCE
   
CHANGE
 
Operating revenue
                       
Base
  $ 134,074     $ 114,948     $ 19,126       16.6  %
Fuel cost recovery
    104,394       137,850       (33,456 )     (24.3 )%
Electric customer credits
    (434 )     -       (434 )     -  
Other operations
    12,243       10,386       1,857       17.9  %
Intercompany revenue
    346       343       3       0.9  %
Operating revenue, net
    250,623       263,527       (12,904 )     (4.9 )%
Operating expenses
                               
Fuel used for electric generation – recoverable
    96,144       92,619       (3,525 )     (3.8 )%
Power purchased for utility customers – recoverable
    8,250       45,263       37,013       81.8  %
Non-recoverable fuel and power purchased
    1,023       4,919       3,896       79.2  %
Other operations
    25,986       24,408       (1,578 )     (6.5 )%
Maintenance
    15,613       11,722       (3,891 )     (33.2 )%
Depreciation
    27,401       22,647       (4,754 )     (21.0 )%
Taxes other than income taxes
    8,388       8,040       (348 )     (4.3 )%
(Gain) loss on sales of assets
    (1 )     40       41       102.5  %
Total operating expenses
    182,804       209,658       26,854       12.8  %
Operating income
  $ 67,819     $ 53,869     $ 13,950       25.9  %
Allowance for other funds used during construction
  $ 1,978     $ 9,805     $ (7,827 )     (79.8 )%
Interest charges
  $ 24,402     $ 18,743     $ (5,659 )     (30.2 )%
Federal and state income taxes
  $ 14,400     $ 12,495     $ (1,905 )     (15.2 )%
Net income
  $ 30,030     $ 32,160     $ (2,130 )     (6.6 )%
 
Cleco Power’s net income in the first quarter of 2011 decreased $2.1 million, or 6.6%, compared to the first quarter of 2010.  Contributing factors include:
 
§  
lower allowance for other funds used during construction,
§  
higher other operations and maintenance expenses,
§  
higher interest charges,
§  
higher depreciation expense, and
§  
higher effective income tax rate.
 
These were partially offset by:
 
§  
higher base revenue,
§  
lower non-recoverable fuel and power purchased, and
§  
higher other operations revenue.


 
38

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 

 
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(MILLION kWh)
 
2011
   
2010
   
FAVORABLE/
(UNFAVORABLE)
 
Electric sales
                 
Residential
    960       1,040       (7.7 )%
Commercial
    594       591       0.5  %
Industrial
    554       544       1.8  %
Other retail
    33       35       (5.7 )%
Total retail
    2,141       2,210       (3.1 )%
Sales for resale
    446       476       (6.3 )%
Unbilled
    (165 )     (124 )     (33.1 )%
Total retail and wholesale customer sales
    2,422       2,562       (5.5 )%

   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2011
   
2010
   
FAVORABLE/
(UNFAVORABLE)
 
Electric sales
                 
Residential
  $ 67,190     $ 46,498       44.5  %
Commercial
    44,092       29,563       49.1  %
Industrial
    20,650       14,160       45.8  %
Other retail
    2,466       1,757       40.4  %
Surcharge
    1,717       4,195       (59.1 )%
Other
    (1,711 )     (975 )     (75.5 )%
Total retail
    134,404       95,198       41.2  %
Sales for resale
    11,939       8,783       35.9  %
Unbilled
    (12,269 )     10,967       (211.9 )%
Total retail and wholesale customer sales
  $ 134,074     $ 114,948       16.6  %
 
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 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 THREE MONTHS ENDED MARCH 31,
 
                     
2011 CHANGE
 
   
2011
   
2010
   
NORMAL
   
PRIOR YEAR
   
NORMAL
 
Heating-degree days
    911       1,307       948       (30.3 )%     (3.9 )%
Cooling-degree days
    139       12       65       *       113.8  %
*Not meaningful
                                       
 
Base
Base revenue increased $19.1 million, or 16.6%, during the first quarter of 2011 compared to the first quarter of 2010.  The base rate increase that became effective in February 2010, which included Madison Unit 3 and Acadia Unit 1, amounted to approximately $39.0 million.  Partially offsetting this increase was $19.9 million in lower base revenue, which was primarily due to lower electric sales, generally resulting from milder winter weather.  Cleco Power expects new industrial load to be added during 2011 and 2012 principally driven by expected development of Haynesville shale gas recently discovered in Northwestern Louisiana.  In addition, Cleco Power also expects to begin providing service to an expansion of a current customer’s operations, as well as services to new customers.  This expansion and service to new customers is expected to contribute base revenue of $4.6 million during the remainder of 2011 and an additional $3.4 million in 2012.  Beginning in July 2011, Cleco Power expects to begin collecting from customers the recovery of completed phases of the Acadiana Load Pocket project.  These collections are expected to contribute base revenue of $7.8 million in 2011 and $12.8 million in 2012.  The project is expected to be completed in 2012.  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, 2010.
 
Fuel Cost Recovery
Fuel cost recovery revenue billed to customers decreased $33.5 million, or 24.3%, during the first quarter of 2011 compared to the first quarter in 2010 primarily due to decreases in the per-unit cost of fuel used for electric generation and power purchased for utility customers.  Also contributing to the decrease was lower volumes of power purchased for utility customers.  Partially offsetting the decrease were higher volumes of fuel used for electric generation.  Higher volumes of fuel used for electric generation and lower volumes of power purchased were primarily due to Madison Unit 3 being placed in service and the acquisition of Acadia Unit 1 during the first quarter of 2010.  Changes in fuel costs historically have not significantly affected Cleco Power’s net income.  Generally, fuel and purchased power expenses are recovered through the LPSC-established fuel adjustment clause, which enables Cleco Power to pass on to its customers substantially all such charges.  Approximately 90% of Cleco Power’s total fuel cost during the first quarter of 2011 was regulated by the LPSC, while the remainder was regulated by FERC.  Recovery of fuel adjustment clause costs is subject to refund until approval is received from the LPSC.  For information on Cleco Power’s current LPSC fuel audit, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 12 — LPSC Fuel Audit.”
 
Other Operations
Other operations revenue increased $1.9 million, or 17.9%, in the first quarter of 2011 compared to the first quarter of 2010 primarily due to $1.3 million of higher mineral lease payments and $0.6 million from the absence of losses related to economic hedge transactions associated with fixed-price power that was provided to a wholesale customer during 2010.  For information on Cleco’s energy commodity activities, see Item 3, “Quantitative and Qualitative Disclosures about Market Risk — Risk Overview — Commodity Price Risks.”
 
 
39

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
Operating Expenses
Operating expenses decreased $26.9 million, or 12.8%, in the first quarter of 2011 compared to the first quarter of 2010.  Fuel used for electric generation (recoverable) increased $3.5 million, or 3.8%, primarily due to higher volumes of fuel used as compared to the first quarter of 2010.  Partially offsetting this increase were lower per unit costs of fuel used for electric generation.  Power purchased for utility customers (recoverable) decreased $37.0 million, or 81.8%, largely due to lower per unit costs and lower volumes of purchased power.  Higher volumes of fuel used for electric generation and lower volumes of power purchased were primarily due to Madison Unit 3 being placed in service and the acquisition of Acadia Unit 1 during the first quarter of 2010.  Fuel used for electric generation and power purchased for utility customers generally are influenced by natural gas prices, as well as availability of transmission.  However, other factors such as scheduled and/or unscheduled outages, unusual maintenance or repairs, or other developments may affect fuel used for electric generation and power purchased for utility customers.  Non-recoverable fuel and power purchased decreased $3.9 million, or 79.2%, primarily due to the commencement of commercial operations of Madison Unit 3 and the acquisition of Acadia Unit 1, which resulted in less capacity purchased from third parties.  Also contributing to the decrease was the absence of non-recoverable expenses primarily related to fixed-price power that was provided to a wholesale customer during 2010.  Other operations expense increased $1.6 million, or 6.5%, primarily due to higher generation operating expenses and higher customer service expenses.  Partially offsetting these increases was lower professional fees.  Maintenance expense increased $3.9 million, or 33.2%, primarily due to higher generating station maintenance work performed during the first quarter of 2011.  Other operations and maintenance expenses for the first quarter of 2011 include the impact of Madison Unit 3 being placed in service and the acquisition of Acadia Unit 1.  Depreciation expense increased $4.8 million, or 21.0%, largely due to Madison Unit 3 being placed in service and the acquisition of Acadia Unit 1.
 
Allowance for Other Funds Used During Construction
Allowance for other funds used during construction decreased $7.8 million, or 79.8%, during the first quarter of 2011 compared to the first quarter of 2010 primarily due to the cessation of AFUDC accruals related to the completion of construction activity at Madison Unit 3.  
 
Interest Charges
Interest charges increased $5.7 million, or 30.2%, during the first quarter of 2011 compared to the first quarter of 2010 primarily due to $3.8 million related to the November 2010 issuance of $250.0 million of senior notes and $2.9 million of lower interest charges capitalized in 2011 compared to 2010 (allowance for borrowed funds used during construction) associated with Madison Unit 3.  Partially offsetting this increase was $1.0 million of lower other miscellaneous interest charges.  
 
Income Taxes
Federal and state income taxes increased $1.9 million, or 15.2%, in the first quarter of 2011 compared to the first quarter of 2010.  The increases include $2.9 million for the change in pre-tax income excluding AFUDC equity and $3.0 million in 2010 related to the implementation of new retail rates approved by the LPSC.  These increases were partially offset by $1.5 million for a Medicare Part D adjustment resulting from new legislation enacted in 2010, $0.2 million for other miscellaneous items, and $2.3 million to record tax expense at the projected annual effective tax rate.
 
Midstream
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
               
FAVORABLE/(UNFAVORABLE)
 
(THOUSANDS)
 
2011
   
2010
   
VARIANCE
   
CHANGE
 
Operating revenue
                       
Tolling operations
  $ 2,781     $ 7,464     $ (4,683 )     (62.7 )%
Other operations
    1       1       -       -  
Affiliate revenue
    33       905       (872 )     (96.4 )%
Operating revenue
    2,815       8,370       (5,555 )     (66.4 )%
Operating expenses
                               
Other operations
    1,817       2,196       379       17.3  %
Maintenance
    1,133       2,064       931       45.1  %
Depreciation
    1,456       1,443       (13 )     (0.9 )%
Taxes other than income taxes
    634       110       (524 )     (476.4 )%
Loss on sales of assets
    12       -       (12 )     *  
Total operating expenses
    5,052       5,813       761       13.1  %
Operating (loss) income
  $ (2,237 )   $ 2,557     $ (4,794 )     (187.5 )%
Equity income from investees
  $ 612     $ 37,846     $ (37,234 )     (98.4 )%
Gain on toll settlement
  $ -     $ 148,402     $ (148,402 )     -  
Interest charges
  $ 583     $ 3,432     $ 2,849       83.0  %
Federal and state income tax (benefit) expense
  $ (683 )   $ 71,388     $ 72,071       101.0  %
Net (loss) income
  $ (1,097 )   $ 114,010     $ (115,107 )     (101.0 )%
*Not meaningful
                               
 
Factors affecting Midstream during the first quarter of 2011 are described below.
 
Operating Revenue
Operating revenue decreased $5.6 million, or 66.4%, in the first quarter of 2011 compared to the first quarter of 2010, largely as a result of lower tolling revenue at Evangeline from the restructuring and pricing of the Evangeline 2010 Tolling Agreement.  Affiliate revenue decreased $0.9 million, or 96.4%, in the first quarter of 2011 compared to the first quarter of 2010 primarily due to Generation Services’ employees who were transferred to Cleco Power during 2010 as a result of the acquisition of Acadia Unit 1.
 
Operating Expenses
Operating expenses decreased $0.8 million, or 13.1%, in the first quarter of 2011 compared to the first quarter of 2010, primarily due to Generation Services’ employees who were transferred to Cleco Power during 2010 in connection with the Acadia Unit 1 transaction and lower maintenance expenses at Evangeline.  Partially offsetting this decrease were higher property taxes.
 
 
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CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
Equity Income from Investees
Equity income from investees decreased $37.2 million, or 98.4%, during the first quarter of 2011 compared to the first quarter of 2010 primarily due to the absence of the gain from Cleco Power’s acquisition of Acadia Unit 1 and half of Acadia Power Station’s related common facilities during 2010.  Partially offsetting the decrease was lower maintenance expenses on Acadia Unit 2.  For additional information on Acadia, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 15 — Acadia Unit 1 Transaction.”  
 
Gain on Toll Settlement
Gain on toll settlement was $148.4 million during the first quarter of 2010 due to transactions related to the termination of the existing Evangeline Tolling Agreement and the execution of the Evangeline 2010 Tolling Agreement.  For additional information, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 14 — Evangeline Transactions.”
 
Interest Charges
Interest charges decreased $2.8 million, or 83.0%, during the first quarter of 2011 compared to the first quarter of 2010 primarily due to the retirement of Evangeline’s debt in 2010.  For additional information, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 14 — Evangeline Transactions.”
 
Income Taxes
Federal and state income taxes decreased $72.1 million, or 101.0%, during the first quarter of 2011 compared to the first quarter of 2010 primarily due to a decrease in pre-tax income.  The effective income tax rate is different than the federal rate due to state tax expense.
 
FINANCIAL CONDITION

Liquidity and Capital Resources
 
General Considerations and Credit-Related Risks
 
Credit Ratings and Counterparties
Financing for operational needs and capital expenditure requirements not satisfied by operating cash flows depends upon the cost and availability of external funds through both short- and long-term financing.  The inability to raise capital on favorable terms could negatively affect Cleco’s or Cleco Power’s ability to maintain or expand its businesses.  Access to funds is dependent upon factors such as general economic and capital market conditions, regulatory authorizations and policies, Cleco Corporation’s and Cleco Power’s credit ratings, the cash flows from routine operations, and the credit ratings of project counterparties.  After assessing the current operating performance, liquidity, and credit ratings of Cleco and Cleco Power, management believes that Cleco 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 March 31, 2011:

 
SENIOR UNSECURED DEBT
 
MOODY’S
 
STANDARD & POOR’S
Cleco Corporation
Baa3
 
BBB-
Cleco Power
Baa2
 
BBB
 
Cleco notes that credit ratings are not recommendations to buy, sell, or hold securities and may be subject to revision or withdrawal at any time by the assigning rating agency.  Each rating should be evaluated independently of any other rating.
For the three-month period ended March 31, 2011, there were no changes to Cleco or Cleco Power’s credit ratings or rating agency’s outlooks.  At March 31, 2011, Moody’s and Standard & Poor’s outlooks for both Cleco Corporation and Cleco Power were stable.  Cleco Corporation and Cleco Power pay fees and interest under their bank credit agreements based on the highest rating held.  If Cleco Corporation or Cleco Power’s credit rating were to be downgraded by Moody’s and Standard & Poor’s, Cleco Corporation and/or Cleco Power would be required to post additional fees and incur higher interest rates under their bank credit agreements.  Cleco Power’s collateral for derivatives is based on the lowest rating held.  If Cleco Power’s credit ratings were to be downgraded by Standard & Poor’s or Moody’s, Cleco Power would be required to post additional collateral for derivatives.  
In August 2005, Cleco Power entered into an EPC contract with Shaw to construct Madison Unit 3.  Under the terms of the Amended EPC Contract, until the final acceptance of Madison Unit 3, in the event Cleco Power does not maintain a senior unsecured credit rating of either: (i) Baa3 or better from Moody’s or (ii) BBB- or better from Standard & Poor’s, Cleco Power will be required to provide a letter of credit to Shaw in the amount of $20.0 million.  In the event of further downgrade to both of its credit ratings to: (i) Ba2 or below from Moody’s, and (ii) BB or below from Standard & Poor’s, Cleco Power will be required to provide an additional $15.0 million letter of credit to Shaw.
With respect to any open power or natural gas trading positions that Cleco may initiate in the future, Cleco may be required to provide credit support or pay liquidated damages.  The amount of credit support that Cleco may be required to provide at any point in the future is dependent on the amount of the initial transaction, changes in the market price of power and natural gas, the changes in open power and gas positions, and changes in the amount counterparties owe Cleco.  Changes in any of these factors could cause the amount of requested credit support to increase or decrease.  
 
Global and U.S. Economic Environment
The current economic environment and uncertainty may have an impact on Cleco’s business and financial condition.  Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows.  Market conditions during the past few years have limited the availability and have increased the costs of capital for many companies.  Although the Registrants have not experienced restrictions in the financial
 
 
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2011 1ST QUARTER FORM 10-Q
 
 
 
markets, their ability to access the capital markets may be restricted at a time when the Registrants would like, or need, to do so.  Any restrictions could have a material impact on the Registrants’ ability to fund capital expenditures or debt service, or on their flexibility to react to changing economic and business conditions. Credit constraints could have a material negative impact on the Registrants’ lenders or customers, causing them to fail to meet their obligations to the Registrants or to delay payment of such obligations.  The lower interest rates that the Registrants have been exposed to have been beneficial to recent debt issuances; however, these rates have negatively affected interest income for the Registrants’ short-term investments.  
 
Fair Value Measurements
Various accounting pronouncements require certain assets and liabilities to be measured at their fair values.  Some assets and liabilities are required to be measured at their fair value each reporting period, while others are required to be measured only one time, generally the date of acquisition or debt issuance.  Cleco and Cleco Power are required to disclose the fair value of certain assets and liabilities by one of three levels when required for recognition purposes under GAAP.  Other financial assets and liabilities, such as long-term debt, are reported at their carrying values at their date of issuance on the consolidated balance sheets with their fair values disclosed without regard to the three levels.  For additional information about fair value levels, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 4 — Fair Value Accounting.”
 
Debt
At March 31, 2011, 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.  
If Cleco Corporation’s credit ratings were to be downgraded one level, Cleco Corporation would be required to pay fees and interest at a rate of 0.25% higher than the current level for its $200.0 million credit facility.  A similar downgrade to the credit ratings of Cleco Power would require Cleco Power to pay fees and interest at a rate of 0.25% higher than the current level on its $300.0 million credit facility.
 
Cleco Consolidated
Cleco had $150.0 million of short-term debt outstanding at March 31, 2011, and December 31, 2010.  The short-term debt outstanding was a bank term loan Cleco Corporation entered into in February 2010.  The bank term loan has an interest rate of LIBOR plus 2.75% and was set to mature in February 2011.  In January 2011, Cleco extended the bank term loan to mature August 19, 2011, and lowered the interest rate to LIBOR plus 2.50% or ABR plus 1.50%.  At March 31, 2011, the interest rate on the term loan was 4.75%.  On April 29, 2011, Cleco repaid the $150.0 million bank term loan.  As part of the repayment, Cleco paid $0.6 million for accrued interest on the term loan.
At March 31, 2011, Cleco’s long-term debt outstanding was $1.4 billion, of which $12.7 million was due within one year, compared to $1.4 billion outstanding at December 31, 2010, which included $12.3 million due within one year.  The long-term debt due within one year at March 31, 2011, represents principal payments for the Cleco Katrina/Rita storm recovery bonds scheduled to be paid in the next twelve months.  
For Cleco, long-term debt at March 31, 2011, decreased $21.6 million compared to December 31, 2010, primarily due to a $15.0 million repayment of Cleco’s credit facility draws and $6.3 million related to a scheduled Cleco Katrina/Rita storm recovery bond principal payment made in March 2011.  
At March 31, 2011, Cleco had a working capital surplus of $0.4 million compared to a working capital surplus of $131.2 million at December 31, 2010.  Included in working capital at March 31, 2011, and December 31, 2010, was $5.4 million and $15.0 million, respectively, which was restricted for the use of debt payments.  The $130.8 million decrease in working capital is primarily due to a decrease in cash and cash equivalents, the recognition of uncertain tax positions and related interest charges expected to be settled in the next 12 months as a current liability, and the reduction of fuel inventories.  Cash and cash equivalents decreased $53.9 million, as discussed below.
Cash and cash equivalents available at March 31, 2011, were $137.2 million combined with $460.0 million facility capacity ($160.0 million from Cleco Corporation and $300.0 million from Cleco Power) for total liquidity of $597.2 million.  Cash and cash equivalents available at March 31, 2011, decreased $53.9 million when compared to cash and cash equivalents available at December 31, 2010.  This decrease is primarily due to the repayment of debt, a contribution to the pension plan, additions to property, plant and equipment, routine working capital fluctuations, and the payment of common dividends.  These decreases were partially offset by a $19.0 million increase from a draw on Shaw’s letter of credit.
At March 31, 2011, 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 additional 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.”
 
Cleco Corporation (Holding Company Level)
Cleco Corporation had $150.0 million short-term debt outstanding at March 31, 2011, and December 31, 2010, in the form of a bank term loan entered into in February 2010.  The bank term loan has an interest rate of LIBOR plus 2.75% and was set to mature in February 2011.  In January 2011, Cleco
 
 
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CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
extended the bank term loan to mature August 19, 2011, and lowered the interest rate to LIBOR plus 2.50% or ABR plus 1.50%.  At March 31, 2011, the interest rate on the term loan was 4.75%.  On April 29, 2011, Cleco repaid the $150.0 million bank term loan.  As part of the repayment, Cleco paid $0.6 million for accrued interest on the term loan.
At March 31, 2011, Cleco Corporation had no outstanding draws under its $200.0 million credit facility compared to $15.0 million outstanding at December 31, 2010.  This credit facility matures on November 23, 2014.  This facility provides for working capital and other needs.  Cleco Corporation’s borrowing costs under the facility are equal to LIBOR plus 2.50%, including facility fees of 0.45%.  An uncommitted line of credit with a bank in an amount up to $10.0 million is available to support Cleco Corporation’s working capital needs.  For additional information about these 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” and “— Disclosures about Guarantees.”
Cash and cash equivalents available at March 31, 2011, were $11.3 million.  Cash and cash equivalents available at March 31, 2011, increased $6.0 million when compared to cash and cash equivalents available at December 31, 2010, primarily due to routine working capital fluctuations.  At March 31, 2011, off-balance sheet commitments reduced available borrowings by $15.0 million.  Additionally, a debt limitation covenant contained in the $150.0 million Cleco Corporation bank term loan agreement limits borrowings to $325.0 million, leaving an available borrowing capacity of $160.0 million.  
 
Cleco Power
There was no short-term debt outstanding at Cleco Power at March 31, 2011, or December 31, 2010.  At March 31, 2011, Cleco Power’s long-term debt outstanding was $1.4 billion, of which $12.7 million was due within one year, compared to $1.4 billion at December 31, 2010, of which $12.3 million was due within one year.  The $12.7 million of long-term debt due within one year at March 31, 2011, represents principal payments for the Cleco Katrina/Rita storm recovery bonds scheduled to be paid in the next twelve months.  For Cleco Power, long-term debt decreased $6.6 million primarily due to a $6.3 million scheduled Cleco Katrina/Rita storm recovery bond principal payment made in March 2011.  
At March 31, 2011, no borrowings were outstanding under Cleco Power’s $300.0 million credit facility.  This facility provides for working capital and other needs.  Cleco Power’s borrowing costs under the facility are equal to LIBOR plus 2.25%, including facility fees of 0.35%.  An uncommitted line of credit with a bank in an amount up to $10.0 million also is available to support Cleco Power’s working capital needs.
At March 31, 2011, and December 31, 2010, Cleco Power had a working capital surplus of $117.0 million and $259.1 million, respectively.  Included in working capital at March 31, 2011, and December 31, 2010, was $5.4 million and $15.0 million, respectively, which was restricted for the use of debt payments.  The $142.1 million decrease in working capital is primarily due to a decrease in cash and cash equivalents, the recognition of uncertain tax positions and related interest charges expected to be settled in the next 12 months as a current liability, and the reduction of fuel inventories.  Cash and cash equivalents decreased $60.5 million, as discussed below.  
Cash and cash equivalents available at March 31, 2011, were $124.4 million, combined with $300.0 million facility capacity for total liquidity of $424.4 million.  Cash and cash equivalents decreased $60.5 million, when compared to cash and cash equivalents at December 31, 2010, primarily due to the repayment of debt, a contribution to the pension plan, and additions to property, plant and equipment.
Cleco Power’s solid waste disposal facility bonds due 2038, and Cleco Power’s GO Zone bonds due 2038, are required to be mandatorily tendered by the holders for purchase on October 1, 2011, and December 1, 2011, respectively, pursuant to the terms of the respective indentures, at which time Cleco Power will have the option to either repay all of Cleco Power’s obligations under the respective loan agreements relating to the bonds or cause the bonds to be remarketed.  Cleco Power expects to cause the bonds to be remarketed for new terms at new interest rates, both to be determined by market conditions.
 
Midstream
Midstream had no short- or long-term debt outstanding at March 31, 2011, or December 31, 2010.
 
Cash Generation and Cash Requirements
 
Restricted Cash
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 general corporate purposes.  At March 31, 2011, and December 31, 2010, $31.7 million and $41.0 million of cash, respectively, was restricted on Cleco Corporation’s Condensed Consolidated Balance Sheets.  At March 31, 2011, restricted cash consisted of $0.1 million under the Diversified Lands mitigation escrow agreement, $1.9 million reserved at Cleco Power for GO Zone project costs, $26.2 million reserved at Cleco Power for future storm restoration costs, and $3.5 million at Cleco Katrina/Rita restricted for payment of operating expenses and interest, and principal on storm recovery bonds.  The $9.3 million net decrease in restricted cash from December 31, 2010, to March 31, 2011, is primarily due to the use of Cleco Katrina/Rita funds for a $6.3 million scheduled storm recovery bond payment made in March 2011 and the use of $4.2 million GO Zone bond funds during the first quarter of 2011.
 
 
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2011 1ST QUARTER FORM 10-Q
 
 
Cleco Cash Flows
 
Net Operating Cash Flow
Net cash provided by operating activities was $26.1 million during the first three months of 2011, compared to $60.8 million during the first three months of 2010.
Cash provided by operating activities during the first three months of 2011 decreased $34.7 million from the first three months of 2010, primarily due to $55.0 million of higher contributions to the pension plan, $50.9 million due to 2011 tax payments compared to 2010 accruals, and the absence of the 2010 collection of a $28.0 million long-term receivable related to the Evangeline transactions.  These were partially offset by $46.2 million of higher collections of customer accounts and receivables unbilled at the end of the prior year, $17.9 million of lower payments to vendors, $19.4 million of higher net income after adjustments for non-cash items, and a $17.0 million change in fuel inventory, primarily due to the sale of fuel oil inventory.
 
Net Investing Cash Flow
Net cash used in investing activities was $43.3 million during the first three months of 2011, compared to $149.6 million during the first three months of 2010.  Net cash used in investing activities during the first three months of 2011 was lower than 2010 primarily due to lower additions to property, plant and equipment.  
During the first three months of 2011, Cleco had additions to property, plant and equipment, net of AFUDC of $43.7 million and a $9.2 million investment in New Market Tax Credits.  This was partially offset by the transfer of $9.4 million of cash from restricted accounts, primarily related to GO Zone bonds and Cleco Katrina/Rita.
During the first three months of 2010, Cleco had additions to property, plant and equipment, net of AFUDC of $173.8 million, an $8.8 million investment in New Market Tax Credits, and a $6.0 million investment in Acadia.  This was partially offset by the transfer of $38.4 million of cash from restricted accounts, primarily related to Evangeline.
 
Net Financing Cash Flow
Net cash used in financing activities was $36.7 million during the first three months of 2011, compared to cash provided by financing activities of $35.8 million during the first three months of 2010.  Net cash provided by financing activities during the first three months of 2011 was lower than the first three months of 2010 primarily due to the absence of short-term debt issuances, partially offset by lower retirements of long-term obligations.  
During the first three months of 2011, Cleco retired $21.3 million of long-term debt, consisting of $15.0 million of credit facility draws and $6.3 million of long-term bonds.  Cleco also used $15.2 million for the payment of common stock dividends.  
During the first three months of 2010, Cleco issued $150.0 million of short-term debt.  This was partially offset by retirements of $101.1 million of long-term debt, consisting of $35.2 million of Evangeline debt, $60.0 million of credit facility draws and $5.9 million of long-term bonds.  Cleco also used $13.6 million for the payment of common stock dividends.
 
Cleco Power Cash Flows
 
Net Operating Cash Flow
Net cash provided by operating activities was $29.1 million during the first three months of 2011, compared to net cash used in operating activities of $12.1 million during the first three months of 2010.
Cash provided by operating activities during the first three months of 2011 increased $41.2 million from the first three months of 2010, primarily due to $52.1 million of higher collections of customer accounts and receivables unbilled at the end of the prior year, $40.9 million of lower payments to vendors and affiliates, and a $17.1 million change in fuel inventory, primarily due to the sale of fuel oil inventory, partially offset by $55.0 million of higher pension plan payments and a $16.8 million change in the non-cash add back of deferred fuel costs.
 
Net Investing Cash Flow
Net cash used in investing activities was $32.7 million during the first three months of 2011, compared to $12.1 million during the first three months of 2010.  Net cash used in investing activities during 2011 was higher than the first three months of 2010 primarily due to higher additions to property, plant and equipment.
During the first three months of 2011, Cleco Power had additions to property, plant and equipment, net of AFUDC of $42.5 million.  This was partially offset by the transfer of $9.4 million of cash from restricted accounts, primarily related to GO Zone bonds and Cleco Katrina/Rita.
During the first three months of 2010, Cleco Power had additions to property, plant and equipment, net of AFUDC of $20.5 million.  This was partially offset by the transfer of $8.3 million of cash from restricted accounts, primarily related to solid waste disposal and GO Zone bonds.
 
Net Financing Cash Flow
Net cash used in financing activities was $56.8 million during the first three months of 2011, compared to $31.4 million during the first three months of 2010.  Net cash used in financing activities during the first three months of 2011 was higher than the first three months of 2010 primarily due to $25.0 million of higher distributions made to Cleco Corporation.
 
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 Consolidated Balance Sheets while other commitments, some firm and some based on uncertainties, are not reflected in the consolidated financial statements.  
For additional information regarding Cleco’s Contractual Obligations and Other Commitments, please read
  
 
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2011 1ST QUARTER FORM 10-Q
 
 
“Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Cash Generation and Cash Requirements — Contractual Obligations and Other Commitments” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Off-Balance Sheet Commitments and Disclosures about Guarantees
Cleco Corporation and Cleco Power have entered into various off-balance sheet commitments, in the form of guarantees and standby letters of credit, in order to facilitate their activities and the activities of Cleco Corporation’s subsidiaries and equity investees (affiliates).  Cleco Corporation and Cleco Power have also agreed to contractual terms that require them to pay third parties if certain triggering events occur.  These contractual terms generally are defined as guarantees in the authoritative guidance.  For additional 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 Matters
 
Wholesale Rates of Cleco
For information on the wholesale rates of Cleco, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Regulatory Matters — Wholesale Rates of Cleco” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Retail Rates of Cleco Power
For information concerning amounts accrued and refunded by Cleco Power as a result of the FRP and information on the Staff’s FRP reviews, see Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 9 — Electric Customer Credits.”
For information on certain other regulatory aspects of retail rates concerning Cleco Power, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Regulatory Matters — Retail Rates of Cleco Power” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Wholesale Electric Markets
For 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 — Liquidity and Capital Resources — Regulatory Matters — Market Restructuring — Wholesale Electric Markets” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
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 — Liquidity and Capital Resources — Regulatory Matters — Retail Electric Markets” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
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 with research into solar projects, a wind project and various other renewable projects.  The RFP component of the program requires utilities, collectively, to issue RFPs for 350 MW of renewable energy, with Cleco Power’s share being 43 MW.  However, because Madison Unit 3 is designed to burn biomass fuel 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.  As part of this process, during the fourth quarter of 2011, Cleco Power expects to perform a biomass test burn at Madison Unit 3.  The projected cost of the test burn is approximately $3.0 million, consisting of $2.0 million of capital modifications, $0.7 million of non-fuel start-up costs, and $0.3 million of biomass fuel.  As a result of deferring the test burn from the second quarter to the fourth quarter of 2011, Cleco Power’s final RFP for biomass fuel along with its written report to the LPSC regarding the cost of co-firing biomass fuel in Madison Unit 3 are now expected to be completed in 2012.  After the LPSC reviews the results of Cleco Power’s RFP, the LPSC may authorize Cleco Power to pursue co-firing biomass fuel in Madison Unit 3 or require Cleco Power to conduct an additional RFP for 43 MW of renewable energy as discussed above.  For additional information on Cleco’s renewable energy pilot program, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations —Financial Condition — Liquidity and Capital Resources — Regulatory Matters — Generation RFP” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Madison Unit 3
In May 2006, Cleco Power began construction of Madison Unit 3, a 600-MW solid fuel power plant.  The unit commenced commercial operations on February 12, 2010.  Madison Unit 3 is capable of burning various solid fuels, but initially began with consumption of petroleum coke produced by several refineries throughout the Gulf Coast region.  Cleco Power had contracted with three refineries to supply various amounts of the Madison Unit 3 fuel requirements though 2014.  Due to pricing and lower than anticipated consumption at Madison 3 in 2010, Cleco terminated one of the three petroleum coke supply contracts effective December 31, 2010.  For economic
 
 
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reasons, in March 2011, Cleco Power purchased 384,000 tons of Illinois basin coal from several suppliers and is assessing the need for additional purchases for the year 2012.
In May 2006, Cleco Power and Shaw entered into an Amended EPC Contract to construct the unit, which contract has subsequently been amended by the parties.  Under the amended contract, the lump-sum price for construction of Madison Unit 3 by Shaw was $795.6 million.  In support of Shaw’s performance obligations, Cleco Power, as of December 31, 2010, retained a letter of credit in the amount of $58.9 million, an additional $0.8 million of payment retainage, as well as a $200.0 million payment and performance bond in favor of Cleco Power as specified under the Amended EPC Contract.  In February 2011, Cleco drew on Shaw’s letter of credit in an amount of $19.0 million due to Shaw’s voidance of a fuel related amendment.  Shaw has yet to replenish the letter of credit on this draw amount as provided under the amended and restated EPC Contract. The retention and outstanding amounts on the letter of credit are provided in support of Shaw’s potential payment of liquidated damages, or other payment performance obligations.
As of March 31, 2011, Cleco Power had incurred approximately $985.6 million in total project costs, including amounts paid under the Amended EPC Contract, AFUDC, and the recovery of $19.0 million from Shaw’s letter of credit.  The Madison Unit 3 budget forecast includes AFUDC, Amended EPC Contract costs, and other development expenses and remains within 1% of its estimated projection of $1.0 billion.  The project achieved commercial operations on February 12, 2010, whereby Cleco Power accepted care, custody, and control of the unit.  Shaw has not reached project completion under the contract, as various performance tests, the reliability test, and specified boiler performance criteria have not been met.  Shaw must correct various identified items, complete various performance guarantee tests, meet a 30-day reliability performance test, and correct various warranty issues.  Cleco Power and Shaw have submitted various claims, relating to the Amended EPC Contract, to arbitration.  On April 30, 2010, Shaw filed a demand for arbitration asserting claims of $32.0 million including impacts due to the 2008 hurricane force majeure, alleged excess fuel moisture, intake water quality and a river embankment slope failure, and the associated recovery of schedule related liquidated damages withheld by Cleco Power.  In May 2010, Cleco Power issued to Shaw a notice of default relating to Shaw’s inability to meet certain material obligations under the Amended EPC Contract.  Furthermore, as a result of Shaw filing the demand for arbitration, certain claims exceeded a $1.0 million threshold, triggering an unwind of certain fuel related matters included in a prior settlement between the parties, Amendment No. 4, and Cleco demanded an associated payment of $19.0 million.  As discussed above, in February 2011, Cleco drew on the Shaw letter of credit in an amount of $19.0 million for amounts relating to the unwind.  Shaw has also amended its demand for arbitration to contest the fuel amendment unwind noted above, and is seeking recovery of such amounts in the on-going arbitration proceedings.  Under the arbitration proceedings, Cleco has also filed compulsory counterclaims for liquidated damages associated with Shaw’s inability to meet various guarantees in the amount of $94.0 million, and up to $320.0 million in warranty claims associated with boiler performance burning petroleum coke.  All of these matters will be resolved by decision of the arbitrator in accordance with the terms of the Amended EPC Contract.  The arbitration process is expected to be completed during the third quarter of 2011.
 
Lignite Deferral
At March 31, 2011, and December 31, 2010, Cleco Power had $21.0 million and $21.7 million, respectively, in deferred lignite mining costs remaining uncollected.  
For additional 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 — Liquidity and Capital Resources — Regulatory Matters — Other Matters — Lignite Deferral” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Acadiana Load Pocket Project
In September 2008, Cleco Power entered into an agreement with two other utilities to upgrade and expand interconnected transmission systems in south central Louisiana in an area known as the Acadiana Load Pocket.  The project received LPSC and SPP approval in February 2009.  Cleco Power’s initial portion of the estimated cost was approximately $150.0 million, including AFUDC.  Due to lower material and labor costs than initially expected, Cleco Power’s estimated costs for its portion of the project has been reduced to $125.0 million, including AFUDC.  At March 31, 2011, Cleco Power had spent $67.5 million on the project and expects to incur an additional $30.7 million during 2011, including AFUDC.  The project is estimated to be 75% complete with the final completion date expected in 2012.  For additional information, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Regulatory Matters — Acadiana Load Pocket Project” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.  For information on the impact the Acadiana Load Pocket project is expected to have on base revenue, see “Results of Operations — Comparison of the Three Months Ended March 31, 2011, and 2010 — Cleco Power — Base.”
 
AMI Project
In May 2010, Cleco Power accepted the terms of a $20.0 million grant from the DOE under the DOE’s small-grant process to implement smart-grid technology for all of Cleco Power’s retail customers.  Cleco Power estimates the project will cost $73.0 million, with the DOE grant providing $20.0 million toward the project and Cleco Power providing the remaining $53.0 million.  The grant program is a part of the American Recovery and Reinvestment Act of 2009, an economic stimulus package passed by Congress in February 2009.  Smart-
 
 
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grid technology includes the installation of electric meters that enable two-way communication capabilities between a home or business and a utility company.  At March 31, 2011, Cleco Power had incurred $2.9 million in AMI costs, of which $1.2 million has been submitted to the DOE for reimbursement.  As of March 31, 2011, Cleco Power had received $0.8 million in payments from the DOE for the AMI project.  The project is expected to be completed in the second quarter of 2013.  For additional information, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Other Matters — AMI Project” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Teche Unit 4 Blackstart Project
In April 2011, Cleco Power completed the work on its project to improve its “blackstart” process (the return of its generation system to service in the event of a total shutdown) as the 33-MW gas turbine at Teche Power Station, which has been designated Teche Unit 4, was placed into commercial operation.  At March 31, 2011, Cleco Power had spent $27.7 million on the project and expects to incur an additional $3.6 million during the remainder of 2011.  For additional information, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — Other Matters — Teche Unit 4 Blackstart Project” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2010.
 
Franchises
Cleco Power’s next municipal franchise expiration is in August 2011 with the City of Opelousas, where approximately 10,000 customers are located.  In 2009, the City of Opelousas conducted a request for proposals from other power companies to potentially replace Cleco Power’s franchise.  The process did not result in successful bids, and subsequently the Mayor formed a citizens committee to determine if the City of Opelousas should operate its own electricity distribution system or continue the operating and franchise agreement with Cleco Power.  In December 2009, the City of Opelousas requested an extension under the operating and franchise agreement to perform the review.  Cleco Power granted extensions until May 16, 2011 and continues to provide service based on the terms of the existing operating and franchise agreement.  For the 12-month period ended March 31, 2011, Cleco Power’s base revenue from the City of Opelousas was $13.4 million.  While the City of Opelousas owns a portion of the electricity distribution system, Cleco Power has performed upgrades and expansions since May 1991, which was the inception of the operating and franchise agreement.  Upon expiration of the operating and franchise agreement, the City of Opelousas is liable to Cleco Power for the depreciated cost of the upgrades and expansions to its distribution system of approximately $9.0 million.
 
Other Franchise Matters
On March 9, 2010, a complaint was filed in the 27th Judicial District Court of St. Landry Parish, State of Louisiana on behalf of three Cleco Power customers in Opelousas, Louisiana.  The complaint alleges that Cleco Power overcharged the plaintiffs by applying to customers in Opelousas the same retail rates as Cleco Power applies to all of its retail customers.  In addition, on May 11, 2010, a second complaint repeating the allegations of the first was filed on behalf of a number of Opelousas residents.  For additional information regarding these complaints, see Part II, Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 11 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — City of Opelousas.”
For additional information on Cleco Power’s 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, 2010.
 
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 to 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.  If Cleco fails to comply with these revisions, reinterpretations and requirements, it could be subject to civil or criminal liabilities and fines.  
On March 16, 2011, the EPA proposed national emissions standards for hazardous air pollutants (NESHAP) from coal- and oil-fired electric utility steam generating units (EGUs) and revisions to new source performance standards (NSPS) for fossil-fuel fired EGUs.  The proposed NESHAP would require affected EGUs to meet specific numeric emission standards and work practice standards for hazardous air pollutants.  The EPA is proposing the NESHAP under Section 112 of the Clean Air Act following a multi-year study of the emissions of hazardous air pollutants from EGUs.  Under Section 112, the EPA must establish emission standards for major sources that “require the maximum degree of reduction in emissions” of hazardous air pollutants that the EPA determines is achievable.  These standards are referred to as “maximum achievable control technology” or “MACT” standards and, for existing units, must be at least as stringent as the average emissions limitations achieved by the best performing twelve percent of existing sources.  For new major sources, the MACT standards must be at least as stringent as the control achieved in practice by the best controlled similar source and may reflect more stringent beyond-the-floor control options.  The proposed
 
 
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CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
NSPS revisions would require new and modified fossil-fired EGUs to meet more stringent SO2, NOx, and PM limits.
The proposed NESHAP would impose emission limits on new and existing coal- and liquid oil- fired EGUs for mercury, acid gases (hydrochloric acid, or HCl, as a surrogate), and non-mercury metallic pollutants (total particulate matter (PM) as a surrogate).  Affected EGUs would also have to comply with certain work practice standards to control the emission of organic air toxins.  Liquid oil-fired units would become subject to different emission limits, but for similar pollutants.  The proposed NESHAP also would impose additional emissions monitoring requirements.  As proposed, Cleco’s liquid oil-fired units would not be affected by the NESHAP unless the use of oil increases as Cleco has not combusted oil in its units in the past three years and has no future plans to combust liquid oil.
If finalized as proposed, the NESHAP is expected to apply to approximately 1,200 coal-fired units across the country.  According to the court order establishing the schedule for the EPA’s rulemaking process, the EPA must issue the final rule by November 16, 2011. The proposed NESHAP would allow existing sources without a case-by-case MACT determination three years to comply, with a one-year extension available with approval by the relevant permitting authority, which in Cleco’s case is the LDEQ.  If the proposed NESHAP becomes effective in early 2012, as scheduled, the approximate compliance date for existing sources would be early 2015, or early 2016, if a one-year extension is granted upon the source’s request.  In the proposed NESHAP, the EPA anticipated that installation of the following levels of additional pollution controls would be required across the country in order to achieve compliance with the proposed rule: 56 GW of dry sorbent injection (DSI), 25 GW of dry flue gas desulfurization, 93 GW of activated carbon injection, 166 GW of fabric filter baghouses.  With the proposal of the NESHAP, Cleco will continue its evaluation of control technology options for Dolet Hills, Madison Unit 3 and Rodemacher Unit 2.  These control options include those mentioned above, among others.  Until a thorough technical and economic evaluation of the control options can be completed, it is difficult at this time to estimate the specific technology and corresponding capital costs or other expenditures necessary to comply with this proposed NESHAP.  However, significant capital expenditures could be required beginning in 2012 to engineer, procure and install pollution controls and emissions monitoring equipment to ensure Cleco will be in a position to comply with the NESHAP in a timely manner.
On March 28, 2011, the EPA proposed regulations which would establish standards for cooling water intake structures at existing power plants and other facilities pursuant to section 316(b) of the Clean Water Act (CWA). The proposed standards respond to decisions by appellate courts remanding earlier EPA efforts to establish section 316(b) standards.  The standards are intended to protect fish and other aquatic wildlife by minimizing capture both in screens attached to intake structures (impingement mortality), and in the actual intake structures themselves (entrainment mortality).  The proposed standards would not impose a uniform requirement to install a closed-cycle cooling system, or cooling towers.  For existing facilities that are designed to draw at least two million gallons per day of water from waters of the United States and use at least twenty-five (25) percent of the water they withdraw exclusively for cooling, the proposed standards would (1) set a performance standard, measured as a fish mortality rate due to impingement, or reduce the flow velocity at cooling water intakes to less than 0.5 feet per second, and (2) require entrainment standards to be determined on a case-by-case basis by state delegated permitting authorities.  As proposed, the rule would require the installation of cooling towers (or a technology of comparable effectiveness) at new units installed at existing facilities.  Facilities subject to the proposed standards would have a maximum of eight years to comply with the impingement requirements, although state permitting authorities would have discretion to set a shorter deadline.  Compliance with entrainment standards would be required “as soon as possible,” by a date to be determined by the same permitting authorities.  At present, the proposed rule appears to be applicable only to Cleco’s Teche and Coughlin facilities.  Until more thorough studies are conducted, including technical and economic evaluations of the control options available, Cleco remains uncertain which technology option or retrofit would be required to be installed on its cooling water intake structures and the associated costs of those modifications assuming that the rule is finalized as proposed; however, the costs of required technology options and retrofits could be significant.
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, 2010.
 
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 accounting principles generally accepted in the United States of America, 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
 
 
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2011 1ST QUARTER FORM 10-Q
 
 
 
updated information or by a change in circumstances or environment.  Actual results may differ significantly from these estimates under different assumptions or conditions.  For a discussion of 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, 2010.
 
CLECO POWER — NARRATIVE ANALYSIS OF RESULTS OF OPERATIONS

Set forth below is information concerning the results of operations of Cleco Power for the three months ended March 31, 2011, and March 31, 2010.  The following narrative analysis should be read in combination with Cleco Power’s Unaudited Condensed Consolidated Financial Statements and the Notes contained in this Combined Quarterly Report on Form 10-Q.
Cleco Power meets the conditions specified in General Instructions H(1)(a) and (b) to Form 10-Q and is therefore permitted to use the reduced disclosure format for wholly owned subsidiaries of reporting companies.  Accordingly, Cleco Power has omitted from this report the information called for by Item 2 (Management’s Discussion and Analysis of Financial Condition and Results of Operations) and Item 3 (Quantitative and Qualitative Disclosures about Market Risk) of Part I of Form 10-Q and the following Part II items of Form 10-Q: Item 2 (Unregistered Sales of Equity Securities and Use of Proceeds) and Item 3 (Defaults upon Senior Securities).  Pursuant to the General Instructions, Cleco Power has included an explanation of the reasons for material changes in the amount of revenue and expense items of Cleco Power between the first quarter of 2011 and the first quarter of 2010.  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, 2010.
For an explanation of material changes in the amount of revenue and expense items of Cleco Power between the first quarter of 2011 and the first quarter of 2010, see “— Results of Operations — Comparison of the Three Months Ended March 31, 2011, and 2010 — Cleco Power” of this Combined Quarterly Report on Form 10-Q, which discussion is incorporated herein by reference.
 
ITEM 3.     QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK


Risk Overview

Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes potential changes arising from changes in interest rates and the commodity market prices of power and natural gas in the industry on different energy exchanges.  Cleco also is subject to market risk associated with its tolling agreement counterparty.  For additional information concerning Cleco’s market risk associated with its counterparty, see Item 2, “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — General Considerations and Credit-Related Risks.”
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.  
Cleco’s exposure to market risk, as discussed below, represents an estimate of possible changes in the fair value or future earnings that would occur, assuming possible future movements in the interest rates and commodity prices of power and natural gas.  Management’s views on market risk are not necessarily indicative of actual results, nor do they represent the maximum possible gains or losses.  The views do represent, within the parameters disclosed, what management estimates may happen.
Cleco monitors credit risk exposure through reviews of counterparty credit quality, aggregate counterparty credit exposure, and aggregate counterparty concentration levels.  Cleco manages these risks by establishing appropriate credit and concentration limits on transactions with counterparties and requiring contractual guarantees, cash deposits or letters of credit from counterparties or their affiliates, as deemed necessary.  Cleco Power has agreements in place with various counterparties that authorize the netting of financial transactions and contract payments to mitigate credit risk for transactions entered into for risk management purposes.
Access to capital markets is a significant source of funding for both short- and long-term capital requirements not satisfied by operating cash flows.  Market conditions during the past few years have limited the availability and have increased the costs of capital for many companies.  The inability to raise capital on favorable terms could negatively affect Cleco’s ability to maintain and expand its businesses.  After assessing the current operating performance, liquidity, and credit ratings of Cleco, management believes that it will have access to the capital markets at prevailing market rates for companies with comparable credit ratings.  Cleco Corporation and Cleco Power pay fees and interest under their respective credit facilities based on the highest rating held.  If Cleco Corporation or Cleco Power’s credit ratings were to be downgraded by Moody’s and Standard & Poor’s, Cleco Corporation or Cleco Power, as the case may be, would be required to pay additional fees and higher interest rates under their respective credit facilities.  Cleco Power’s collateral for derivatives is based on the lowest rating held.  If Cleco Power’s credit ratings were to be downgraded by Standard & Poor’s or Moody’s, Cleco Power would be required to pay additional collateral for derivatives.
 
 
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CLECO POWER       
2011 1ST QUARTER FORM 10-Q
 
 
 
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 fixed-rate obligations is computed by calculating the current fair market value using a net present value model based upon a 1% change in the average interest rate applicable to such debt.  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 March 31, 2011, Cleco had $150.0 million of short-term variable rate debt outstanding.  The bank term loan was set to expire February 2011.  In January 2011, Cleco extended the bank term loan to mature on August 19, 2011, and lowered the interest rate to LIBOR plus 2.50% or ABR plus 1.50%.  At March 31, 2011, the interest rate on the bank term loan was 4.75%.  On April 29, 2011, Cleco repaid the $150.0 million bank term loan.  As part of the repayment, Cleco paid $0.6 million for accrued interest on the term loan.  Each 1% increase in the interest rate applicable to such debt would have resulted in a $1.5 million decrease in pre-tax earnings of Cleco.
At March 31, 2011, Cleco Corporation had no borrowings outstanding under its $200.0 million four-year credit facility.  
At March 31, 2011, Cleco had no long-term variable rate debt outstanding.  Cleco Power’s solid waste disposal facility bonds due 2038, and Cleco Power’s GO Zone bonds due 2038, are required to be mandatorily tendered by the holders for purchase on October 1, 2011, and December 1, 2011, respectively, pursuant to the terms of the respective indentures, at which time Cleco Power will have the option to either repay all of Cleco Power’s obligations under the respective loan agreements relating to the bonds or cause the bonds to be remarketed. Cleco Power expects to cause the bonds to be remarketed for new terms at new interest rates, both to be determined by market conditions.  
 
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), regulatory compliance staff, as well as monitoring by a risk management committee comprised of officers and the General Manager – Internal Audit, who are approved by Cleco Corporation’s Board of Directors.  Risk limits are recommended by the Risk Management Committee and monitored through a daily risk report that identifies the current VaR, current market conditions, and concentration of energy market positions.
Cleco Power provides fuel for generation and purchases power to meet the power demands of customers.  Cleco Power has entered into positions to mitigate the volatility in customer fuel costs, as encouraged by an LPSC order.  Cleco Power’s fuel stabilization policy targets higher levels of minimum hedging percentages and mitigates the volatility in customer fuel costs.  The change in positions could result in increased volatility in the marked-to-market amounts for the financial positions.  These positions are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of the accumulated deferred fuel asset or liability and a component of the risk management assets or liabilities.  When these positions close, actual gains or losses are deferred and included in the fuel adjustment clause in the month the physical contract settles.  Based on market prices at March 31, 2011, the net mark-to-market impact related to open natural gas positions at March 31, 2011, were losses of $11.8 million.  The majority of these natural gas positions will close over the next twelve months.  Deferred losses relating to closed natural gas positions at March 31, 2011, and December 31, 2010, totaled $1.7 million and $1.6 million, respectively.  
Cleco utilizes a VaR model to assess the market risk of its hedging portfolios, including derivative financial instruments.  VaR represents the potential loss in fair value for an instrument from adverse changes in market factors over a defined period of time with a specified confidence level.  VaR is calculated daily, using the variance/covariance method with delta approximation, assuming a holding period of one day, and a 95% confidence level for natural gas and power positions.  Volatility is calculated daily from historical forward prices using the exponentially weighted moving average method.
Based on these assumptions, the VaR relating to Cleco Power’s hedge transactions for the three months ended March 31, 2011, as well as the VaR at December 31, 2010, is summarized below.

   
FOR THE THREE MONTHS
 ENDED MARCH 31, 2011
   
AT MARCH 31,
   
AT DECEMBER 31,
 
(THOUSANDS)
 
HIGH
   
LOW
   
AVERAGE
   
2011
   
2010
 
Fuel cost hedges
  $ 1,458.3     $ 984.0     $ 1,183.8     $ 1,220.8     $ 1,346.0  
 
 
 
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Cleco Power

Please refer to “— Risk Overview” above 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” above for a discussion of how Cleco Power monitors its mix of fixed- and variable-rate debt obligations and the manner of calculating changes in fair market value and interest expense of its debt obligations.  
Cleco Power had no short- or long-term variable-rate debt as of March 31, 2011.
At March 31, 2011, Cleco Power had no borrowings outstanding under its $300.0 million four-year credit facility.
Please refer to “— Commodity Price Risks” above for a discussion of controls, transactions, VaR, and market value maturities associated with Cleco Power’s energy commodity activities.  


ITEM 4.      CONTROLS AND PROCEDURES


Evaluation of Disclosure Controls and Procedures
As of March 31, 2011, evaluations were performed under the supervision and with the participation of Cleco Corporation and Cleco Power LLC (individually, “Registrant” and collectively, the “Registrants”) management, including the Chief Executive Officer (CEO) and Chief Financial Officer (CFO).  The evaluations assessed the effectiveness of the Registrants’ disclosure controls and procedures.  Based on the evaluations, the CEO and CFO have concluded that the Registrants’ disclosure controls and procedures are effective to ensure that information required to be disclosed by each Registrant in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in Securities and Exchange Commission 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 Controls over Financial Reporting
Under the supervision and with the participation of the Registrants’ management, including the CEO and CFO, the Registrants evaluated changes in internal control over financial reporting that occurred during the quarter ended March 31, 2011, and found no change that has materially affected, or is reasonably likely to materially affect, internal control over financial reporting.
 
 
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2011 1ST QUARTER FORM 10-Q
 
 
 
PART II — OTHER INFORMATION

 
ITEM 1. LEGAL PROCEEDINGS

CLECO

For information on legal proceedings affecting Cleco, see Part I, Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 11 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation.”
 
CLECO POWER

For information on legal proceedings affecting Cleco Power, see Part I, Item 1, “Notes to the Unaudited Condensed Consolidated Financial Statements — Note 11 — Litigation, Other Commitments and Contingencies, and Disclosures about Guarantees — Litigation.”
 
 
ITEM 1A.   RISK FACTORS

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, 2010 (the “2010 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 2010 Annual Report on Form 10-K.  
 
 ITEM 5.    OTHER INFORMATION


Departure of Directors
Effective April 29, 2011, Richard B. Crowell retired as a director of Cleco Corporation.  Mr. Crowell has served as a director of Cleco Corporation since 1997 and has reached the retirement age for outside directors specified in Cleco Corporation’s Bylaws.
Effective April 29, 2011, W. Larry Westbrook retired as a director of Cleco Corporation.  Mr. Westbrook has served as a director of Cleco Corporation since 2003 and has reached the retirement age for outside directors specified in Cleco Corporation’s Bylaws.

Amendment to Bylaws
Effective April 29, 2011, and in connection with the retirement of Messrs. Crowell and Westbrook, the Board of Directors of Cleco Corporation amended Cleco Corporation’s Bylaws to decrease the number of directors serving on the board to ten.  Prior to the amendment, the Bylaws provided for twelve directors to serve on the board.  The text of the amendment is filed as Exhibit 3.1 to this Combined Quarterly Report on Form 10-Q.

Closing of Acadia Unit 2 Transaction
On April 29, 2011, Acadia completed the sale of Acadia Unit 2 and half of Acadia Power Station’s related common facilities to Entergy Louisiana for approximately $300 million.  Cleco Corporation indirectly owns 50 percent of Acadia through APH.  APH received approximately $150 million from the sale transaction.  APH’s portion of the proceeds from the sale transaction were used to repay Cleco Corporation’s $150.0 million bank term loan.  In addition, in exchange for $10.9 million, APH indemnified the third party owners of Cajun and their affiliates against 50% of Acadia’s liabilities and other obligations related to the Acadia Unit 2 transaction.  APH recognized a gain of approximately $60.0 million from the Acadia Unit 2 transaction.  Cleco Power operates Acadia Unit 2 on behalf of Entergy Louisiana.

 
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2011 1ST QUARTER FORM 10-Q
 

 
ITEM 6. EXHIBITS


CLECO CORPORATION
 
3.1
Bylaws of Cleco Corporation, Revised effective April 29, 2011
 
12(a)
Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Stock Dividends for the three- and twelve-month periods ended March 31, 2011, 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
 
101.INS*
XBRL Instance Document
 
101.SCH*
XBRL Taxonomy Extension Schema
 
101.CAL*
XBRL Taxonomy Extension Calculation Linkbase
 
101.DEF*
XBRL Taxonomy Extension Definition Linkbase
 
101.LAB*
XBRL Taxonomy Extension Label Linkbase
 
101.PRE*
XBRL Taxonomy Extension Presentation Linkbase
 
CLECO POWER
 
12(b)
Computation of Ratios of Earnings to Fixed Charges for the three- and twelve-month periods ended March 31, 2011, 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
 
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
 
   
*XBRL information is furnished and not filed for purposes of Sections 11 and 12 of the Securities Act of 1933 and Section 18 of the Securities Exchange Act of 1934, and is not subject to liability under those sections, is not part of any registration statement or prospectus to which it relates and is not incorporated or deemed to be incorporated by reference into any registration statement, prospectus or other document.
 
 
 
53

 
CLECO CORPORATION
 
CLECO POWER       
2011 1ST 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/ R. Russell Davis                                                                             
 
R. Russell Davis
 
Vice President - Investor Relations & Chief Accounting Officer




Date:  May 4, 2011




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/ R. Russell Davis                                                                             
 
R. Russell Davis
 
Vice President - Investor Relations & Chief Accounting Officer




Date:  May 4, 2011

54


EX-3.1 2 exhibit31.htm EXHIBIT 3.1 - BYLAWS OF CLECO CORPORATION, REVISED EFFECTIVE APRIL 29, 2011 exhibit31.htm


EXHIBIT 3.1


 







BYLAWS

OF

CLECO CORPORATION

(Revised effective April 29, 2011
as approved by the Board on March 15, 2011)
 
 
 
 
 
 
 
 
 
 

 
 

 
ARTICLE I
Registered Office; Registered Agents; Corporate Seal
1
     
Section 1.
Registered Office and Registered Agent(s) 
1
Section 2.
Corporate Seal 
1
     
ARTICLE II
Shareholders
1
     
Section 1.
Place of Holding Meetings 
1
Section 2.
Quorum; Adjournment of Meetings 
1
(a)
General Rule 
1
(b)
Special Rule 
1
(c)
Adjournments 
2
Section 3.
Annual Meeting 
2
Section 4.
Special Meeting 
2
Section 5.
Conduct of Meetings 
3
Section 6.
Voting 
4
Section 7.
Notice 
5
Section 8.
Amendment of Articles of Incorporation 
8
(a)
Shareholders Proposals 
8
(b)
Effectiveness 
8
Section 9.
Effectiveness of Other Amendments to Articles of Incorporation 
9
Section 10.
General 
10
     
ARTICLE III
Directors
10
     
Section 1.
Certain General Provisions 
10
(a)
Number 
10
(b)
Classifications 
10
(c)
Nominations 
10
(d)
Qualifications; Declaration of Vacancy 
12
(e)
Removal 
13
(f)
Powers 
14
(g)
Change in Number of Directors 
15
(h)
Rights of Preferred Shareholders, etc. 
15
Section 2.
Filling of Vacancies 
15
Section 3.
Annual and Regular Meetings 
15
Section 4.
Special Meetings 
16
Section 5.
Place of Meetings; Telephone Meetings 
16
Section 6.
Quorum 
16
Section 7.
Compensation 
16
Section 8.
Committees 
16
     
ARTICLE IV
Indemnification
17
     
Section 1.
Right to Indemnification – General 
17
 
 
 
 

 
 
 
Section 2.
Certain Provisions Respecting Indemnification for and Advancement of Expenses
17
Section 3.
Procedure for Determination of Entitlement to Indemnification 
18
Section 4.
Presumptions and Effect of Certain Proceedings 
19
Section 5.
Right of Claimant to Bring Suit 
19
Section 6.
Non-Exclusivity and Survival of Rights 
20
Section 7.
Definitions 
21
     
ARTICLE V
Executive Committee
22
     
Section 1.
Election and Tenure 
22
Section 2.
Executive Committee 
22
Section 3.
Meetings 
22
Section 4.
Compensation 
22
     
ARTICLE VI
Audit Committee
22
     
Section 1.
Election and Tenure 
22
Section 2.
Audit Committee 
22
Section 3.
Meetings 
23
Section 4.
Compensation 
23
     
ARTICLE VII
Compensation Committee
23
     
Section 1.
Election and Tenure 
23
Section 2.
Compensation Committee 
23
Section 3.
Meetings 
23
Section 4.
Compensation 
23
     
ARTICLE VII.A.
Nominating/Governance Committee
24
     
Section 1.
Election and Tenure 
24
Section 2.
Nominating/Governance Committee 
24
Section 3.
Meetings 
24
Section 4.
Compensation 
24
     
ARTICLE VIII
Officers
24
     
Section 1.
Election, Tenure, and Compensation 
24
Section 2.
Powers and Duties of Chairman of Board of Directors 
25
Section 3.
Powers and Duties of President 
25
Section 4.
Powers and Duties of Vice President 
25
Section 5.
Powers and Duties of Secretary 
25
Section 6.
Powers and Duties of Treasurer 
25
Section 7.
Delegation of Duties 
26
     
 
 
ii

 
 
 
 
     
ARTICLE IX
Capital Stock
26
     
Section 1.
Stock Certificates 
26
Section 2.
Lost or Destroyed Certificates 
26
Section 3.
Transfer of Shares 
26
Section 4.
Dividends 
27
Section 5.
Closing Transfer Books; Fixing Record Date 
27
     
ARTICLE X
Fair-Price Provisions
27
     
Section 1.
Definitions 
27
Section 2.
Vote Required in Business Combinations 
30
Section 3.
When Voting Requirements Not Applicable 
31
(a)
Definitions 
31
(b)
Conditions 
31
(c)
Other Provisions 
34
     
ARTICLE XI
Notices
34
     
Section 1.
Manner of Giving Notice 
34
Section 2.
Waiver of Notice 
34
     
ARTICLE XII
Miscellaneous
35
     
Section 1.
Fiscal Year 
35
Section 2.
Checks and Drafts 
35
Section 3.
Books and Records 
35
Section 4.
Separability 
35
     
ARTICLE XIII
Amendment of Bylaws
35
     
Section 1.
Voting 
35
Section 2.
Shareholder Proposals 
35
Section 3.
Effective Date 
36
     
ARTICLE XIV
Other Amendments to Bylaws
36
     
Section 1.
Effective Date 
36
     
ARTICLE XV
Control Share Acquisition Statute
37
     
Section 1.
 
37
     
 
 
 
iii

 

BYLAWS

OF

CLECO CORPORATION


ARTICLE I
 
Registered Office; Registered Agents; Corporate Seal
 
Section 1.             Registered Office and Registered Agent(s).  The registered office of the Corporation is 2030 Donahue Ferry Road, Pineville, Louisiana 71360-5226, and its registered agents are the president and chief executive officer of the Corporation, the general counsel, and the manager of insurance and claims of the Corporation, post office address 2030 Donahue Ferry Road, Pineville, Louisiana 71360-5226.  The Corporation may also have offices at such other places as the board of directors, the chief executive officer or the president may from time to time designate.

Section 2.             Corporate Seal.  The corporate seal of the Corporation shall be circular in form and have inscribed on its periphery the words “Cleco Corporation 1999” and in its center the words “Corporate”, “Seal” and “Louisiana.”

ARTICLE II
 
Shareholders

Section 1.             Place of Holding Meetings.  All meetings of the shareholders shall be held at the principal office of the Corporation in the City of Pineville, State of Louisiana, except in cases in which the notices thereof designate some other place, which may be within or without the State of Louisiana.

Section 2.             Quorum; Adjournment of Meetings.

(a)           General Rule.  Except as otherwise provided in these bylaws, the presence in person or by proxy at a meeting of shareholders of the holders of record of a number of the shares of the capital stock of the Corporation issued and outstanding and entitled to vote thereat that represents a majority of the votes entitled to be cast thereat shall constitute a quorum at such meeting.

(b)           Special Rule.  At a meeting of shareholders at least one purpose of which is to amend or repeal a provision of or to supplement these bylaws or the articles of incorporation of the Corporation or to act on a merger, consolidation, reclassification, repurchase, or exchange of securities, transfer of all or substantially all of the assets of the Corporation, dissolution, “business combination” as defined in article X of these bylaws, or similar transaction, a quorum shall for all purposes consist of the presence in person or by proxy at such meeting of the holders of the number of the shares of the capital stock of the Corporation issued and outstanding and entitled to
 
 
1

 
 
 
vote thereat that represents 80% of the votes entitled to be cast thereat. At a meeting described in the preceding sentence, the quorum for any class of shares entitled to vote as a class shall be the holders of the number of shares of such class that represents 80% of the votes entitled to be cast by all holders of all shares of such class. Notwithstanding the foregoing, if the change in the articles of incorporation or bylaws, merger, consolidation, reclassification, repurchase, or exchange of securities, transfer of all or substantially all of the assets of the Corporation,  dissolution, “business combination” as defined in article X of these bylaws, or similar transaction in question shall have been approved, before submission of a proposal relating thereto to a vote of shareholders, by at least 80% of the “continuing directors” (hereinafter defined) of the Corporation, then, instead of subsection (b), subsection (a) of this section 2 shall determine the quorum at the meeting of shareholders at which such proposal is considered by shareholders.  For purposes of the preceding, a “continuing director” shall mean a director elected pursuant to a solicitation of proxies by the board of directors of the Corporation at an annual meeting of shareholders held at least 90 days before the date of determination and who has served continuously since such election, or a director elected by continuing directors to fill a vacancy.

(c)           Adjournments.  A meeting may, whether or not a quorum shall be in attendance at the time for which such meeting shall have been called and without any notice other than by announcement at such meeting, be adjourned from time to time by the chairman of the board of directors or the vote of the shareholders present in person or by proxy representing a majority of the votes so present, for a period not exceeding one month at any one time; provided, however, that a meeting at which a director or directors are to be elected shall be adjourned only from day to day until such director or directors have been elected.  At an adjourned meeting at which a quorum shall attend, any business may be transacted which might have been transacted if such meeting had been held as originally called.

Section 3.             Annual Meeting.  Except as otherwise provided by resolution of the board of directors, the annual meeting of shareholders for the election of directors shall be held on the third Friday after the first Monday in April of each year.  At each annual meeting, the shareholders shall elect directors to succeed those whose terms have expired as of the date of such annual meeting.  Such other matters as may properly come before a meeting may be acted upon at an annual meeting.

Section 4.             Special Meeting.

(a)           Special meetings of the shareholders for any purpose or purposes may be called by the chief executive officer or president, by a majority of the board of directors, or by a majority of the executive committee, if any, of the board of directors; provided, however, that if and whenever dividends payable on any series of the Corporation’s preferred stock shall be in default in an amount equal to the aggregate dividends payable in any period of 12 consecutive calendar months, a special meeting shall be called on the demand in writing of the holders of record of a majority of the outstanding shares of preferred stock; and, provided further, that a special meeting of shareholders may be called by a shareholder or shareholders as provided in the Corporation’s articles of incorporation, these bylaws, or otherwise by law.

(b)           Any shareholder requesting that a special meeting of shareholders be called (the
 
 
 
2

 
 
 
 “Requesting Person”) shall, at the time of making the request, be a shareholder and submit written evidence, reasonably satisfactory to the secretary of the Corporation, that the Requesting Person is a shareholder of the Corporation and shall identify in writing (i) all information required to be included in a shareholder’s notice to bring business before a meeting of shareholders, as set forth in section 7(b)(3) of article II of these bylaws, and (ii) the reason or reasons for which the special meeting is to be called.  Within 15 days after the Requesting Person has submitted the aforesaid items to the secretary of the Corporation, the secretary of the Corporation shall determine whether the evidence of the Requesting Person’s status as a shareholder submitted by the Requesting Person is reasonably satisfactory and shall notify the Requesting Person in writing of his determination.  If the Requesting Person fails to submit the requisite information in the form or at the time indicated, or if the secretary of the Corporation fails to find such evidence of shareholder status reasonably satisfactory, then the request to call a special meeting of shareholders shall be deemed invalid (by reason of failure to comply with these bylaws) and no special meeting of shareholders shall be held pursuant to such request.  Nothing in this subsection (b) shall affect the rights of the Corporation’s shareholders as provided in section 3(b) of article 6 of the Corporation’s articles of incorporation or as provided in subsection (a) immediately preceding with respect to the rights of the Corporation’s preferred shareholders.

Section 5.             Conduct of Meetings.  Meetings of shareholders shall be presided over by the chief executive officer or president of the Corporation or, if the chief executive officer or president is not present at a meeting, by such other person as the board of directors shall designate or, if no such person is designated by the board of directors, the most senior officer of the Corporation present at the meeting.  The secretary of the Corporation, if present, shall act as secretary of each meeting of shareholders; if he is not present at a meeting, then such person as may be designated by the presiding officer shall act as secretary of the meeting.  Meetings of shareholders shall follow reasonable and fair procedure.  Subject to the foregoing, the conduct of any meeting of shareholders and the determination of procedure and rules shall be within the absolute discretion of the presiding officer (the “Chairman of the Meeting”), and there shall be no appeal from any ruling of the Chairman of the Meeting with respect to procedure or rules.  Accordingly, in any meeting of shareholders or part thereof, the Chairman of the Meeting shall have the sole power to determine appropriate rules or to dispense with theretofore prevailing rules.  Without limiting the foregoing, the following rules shall apply:

(a)           The Chairman of the Meeting may ask or require that anyone not a bona fide shareholder or proxy leave the meeting.

(b)           A resolution or motion shall be considered for vote only if proposed by a shareholder or duly authorized proxy, and seconded by an individual, who is a shareholder or a duly authorized proxy, other than the individual who proposed the resolution or motion, subject to compliance with any other requirements concerning such a proposed resolution or motion contained in these bylaws.  The Chairman of the Meeting may propose any motion for vote.  The order of business at all meetings of shareholders shall be determined by the Chairman of the Meeting.

(c)           The Chairman of the Meeting may impose any reasonable limits with respect to participation in the meeting by shareholders, including, but not limited to, limits on the amount of
 
 
 
3

 
 
time at the meeting taken up by the remarks or questions of any shareholder, limits on the numbers of questions per shareholder, and limits as to the subject matter and timing of questions and remarks by shareholders.

(d)           Before any meetings of shareholders, the board of directors may appoint any persons other than nominees for office to act as inspectors of election at the meeting or its adjournment.  If no inspectors of election are so appointed, the Chairman of the Meeting may, and on the request of any shareholder or a shareholder’s proxy shall, appoint inspectors of election at the meeting of shareholders.  The number of inspectors shall be three.  If any person appointed as inspector fails to appear or fails or refuses to act, the Chairman of the Meeting may, and upon the request of any shareholder or a shareholder’s proxy shall, appoint a person to fill such vacancy.
The duties of these inspectors shall be as follows:

(1)           Determine the number of shares outstanding and the voting power of each, the shares represented at the meeting, the existence of a quorum, and the authenticity, validity and effect of proxies;

(2)           Receive votes or ballots;

(3)           Hear and determine all challenges and questions in any way arising in connection with the right to vote;

(4)           Count and tabulate all votes;

(5)           Report to the board of directors the results based on the information assembled by the inspectors; and

(6)    Do any other acts that may be proper to conduct the election or vote with fairness to all shareholders.

Notwithstanding the foregoing, the final certification of the results of any election or other matter acted upon at a meeting of shareholders shall be made by the board of directors.

Section 6.             Voting.  Except as otherwise provided by the articles of incorporation, each holder of shares of capital stock of the Corporation shall be entitled, at each meeting of shareholders, to one vote for each share of such stock standing in his name on the books of the corporation on the date of such meeting or, if the board of directors, pursuant to section 5 of article IX of these bylaws, shall have fixed a record date for the purpose of such meeting or shall have fixed a date as of which the books of the Corporation shall be temporarily closed against transfers of shares, then as of such date; except that in the election of directors of the Corporation, each holder of shares of common stock of the Corporation shall have the right to multiply the number of votes to which he may be entitled by the number of directors to be elected, and he may cast all such votes for one candidate or he may distribute them among any two or more candidates.  A shareholder may vote either in person or by proxy appointed by an instrument in writing, subscribed by such shareholder or by his duly authorized attorney.  Except as otherwise provided by law, the articles of incorporation, or these bylaws, all elections shall be had and all questions
 
 
 
4

 
 
 
shall be decided by a majority of the votes cast at a duly constituted meeting at which a quorum is present.

Section 7.             Notice.

(a)           Unless otherwise provided by the articles of incorporation, written or printed notice, stating the place, day, and hour of each meeting of shareholders, and, in the case of a special meeting, the business proposed to be transacted thereat, shall be given in the manner provided in article XI of these bylaws to each shareholder entitled to vote at such meeting, at least 15 days before an annual meeting and at least five days before a special meeting.

(b)
 
(1)      Except as provided in subsection (c) of this section, to be properly brought before any meeting of the shareholders, business must be either (i) specified in the notice of meeting (or any supplement thereto) given by or at the direction of the board of directors pursuant to subsection (a) of this section 7, (ii) otherwise properly brought before the meeting by or at the direction of the board of directors, or (iii) otherwise properly brought before the meeting by a shareholder who (A) is a shareholder at the time of the giving of such shareholder’s notice provided for in this section 7, (B) shall be a holder of record entitled to vote at the meeting and (C) complies with the requirements of this section 7.  Clause (iii) of the immediately preceding sentence shall be the exclusive means for a shareholder to submit business or proposals (other than matters properly brought under Rule 14a-8 under the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and included in the notice relating to the meeting (or any supplement thereto) given in accordance with subsection (a) of this section 7) before any meeting of shareholders.
 
 
(2)           In addition to any other applicable requirements, for business to be properly brought before any meeting by a shareholder, the shareholder must have given timely notice thereof in writing to the secretary of the Corporation.  To be timely, a shareholder’s notice must be delivered to or mailed and received at the principal executive offices of the Corporation at least 120 days prior to the meeting; provided, however, that in the event that less than 135 days’ notice or prior public disclosure of the date of any meeting of shareholders is given or made to shareholders by the Corporation, notice by the shareholder to be timely must be so received not later than the close of business of the 15th day following the day on which such notice of the date of the meeting was mailed or such public disclosure was made, whichever first occurs.  In no event shall any adjournment, postponement or deferral of a meeting of shareholders or the announcement thereof commence a new time period for the giving of a shareholder’s notice as described above.

(3)           Any such shareholder’s notice to the secretary of the Corporation shall set forth in writing as to each matter the shareholder proposes to bring before any meeting of the shareholders (i) a brief description of the business desired to be brought before the meeting and the reasons for conducting such business at the meeting, (ii) as to the shareholder proposing such business and the beneficial owner, if any, on whose behalf the proposal is made, (A) the name and record address of the shareholder proposing such business, as they appear on the Corporation’s books, and of the beneficial owner, if any,
 
 
 
5

 
 
 
 
(B) the name and address of all other persons known by such shareholder and beneficial owner, if any, to be supporting such business (“Supporting Person”), (C) the class or series and number of shares of the Corporation which are, directly or indirectly, owned beneficially and of record by each of the shareholder, beneficial owner and Supporting Person, (D) any option, warrant, convertible security, stock appreciation right or similar right with an exercise or conversion privilege or a settlement payment or mechanism at a price related to any class or series of shares of capital stock of the Corporation or with a value derived in whole or in part from the price, value or volatility of any class or series of shares of capital stock of the Corporation or any derivative or synthetic arrangement having characteristics of a long position in any class or series of shares of capital stock of the Corporation, whether or not such instrument or right shall be subject to settlement in the underlying class or series of capital stock of the Corporation or otherwise (a “Derivative Instrument”) directly or indirectly owned beneficially by such shareholder and by such beneficial owner and any other direct or indirect opportunity to profit or share in any profit derived from any increase or decrease in the value of shares of capital stock of the Corporation, (E) any proxy, contract, arrangement, understanding or relationship the effect or intent of which is to increase or decrease the voting power of such shareholder or beneficial owner with respect to any shares or any security of the Corporation, (F) any pledge by such shareholder or beneficial owner of any security of the Corporation or any short interest of such shareholder or beneficial owner in any security of the Corporation (a person shall be deemed to have a short interest in a security if such person directly or indirectly, through any contract, arrangement, understanding, relationship or otherwise, has the opportunity to profit or share in any profit derived from any decrease in the value of the subject security), (G) any rights to dividends on the shares of capital stock of the Corporation owned beneficially by such shareholder and by such beneficial owner that are separated or separable from the underlying shares of capital stock of the Corporation, (H) any proportionate interest in shares of capital stock of the Corporation or Derivative Instruments held, directly or indirectly, by a general or limited partnership in which such shareholder or beneficial owner is a general partner or, directly or indirectly, beneficially owns an interest in a general partner, (I) any performance-related fees (other than an asset-based fee) that such shareholder or beneficial owner is entitled to based on any increase or decrease in the value of shares of capital stock of the Corporation or Derivative Instruments, if any, as of the date of such notice, including, without limitation, any such interests held by members of such shareholder’s or beneficial owner’s immediate family sharing the same household, (J) a representation regarding whether such shareholder or beneficial owner intends to solicit proxies with respect to the business desired to be brought before the meeting and (K) a representation regarding whether such shareholder or beneficial owner intends to appear in person or by proxy at the meeting, (iii) any other information relating to such shareholder and beneficial owner, if any, that would be required to be disclosed in solicitations of proxies for the proposal, or would otherwise be required, in each case pursuant to section 14 of the Exchange Act and the rules and regulations promulgated thereunder; (iv) any material interest of such shareholder, any such beneficial owner and any Supporting Person in such business or proposal and (v) a description of all agreements, arrangements and understandings between such shareholder and beneficial owner, if any, and any other person or persons (including their names) in connection with such business or proposal by such shareholder.  Beneficial ownership shall
 
 
6

 
 
 
be determined in accordance with section 1 of article X of these bylaws.

(4)           A shareholder providing notice of business proposed to be brought before a meeting of shareholders shall further update and supplement such notice, if necessary, so that the information provided or required to be provided in such notice pursuant to subsection (b) of this section 7 shall be true and correct as of the record date for the meeting and as of the date that is ten business days prior to the meeting, including any adjournment or postponement thereof, and such update and supplement shall be delivered to, or mailed and received by, the secretary of the Corporation not later than five business days after the record date for the meeting (in the case of the update and supplement required to be made as of the record date), and not later than eight business days prior to the date for the meeting, if practicable (or, if not practicable, on the first practicable date prior to), including any adjournment or postponement thereof (in the case of the update and supplement required to be made as of ten business days prior to the meeting or any adjournment or postponement thereof).  In addition, a shareholder providing notice of business proposed to be brought before an annual meeting shall update and supplement such notice, and deliver such update and supplement to the principal executive offices of the Corporation, promptly following the occurrence of any event that materially changes the information provided or required to be provided in such notice pursuant to subsection (b) of this section 7.

(5)           Except as provided in subsection (c) of this section 7, notwithstanding anything in these bylaws to the contrary, no business shall be conducted at any meeting of the shareholders except in accordance with the procedures set forth in this section 7 of article II, provided, however, that nothing in this section 7 of article II shall be deemed to preclude discussion by any shareholder as to any business properly brought before any meeting of the shareholders.  In addition to the foregoing provisions of this section 7, a shareholder of the Corporation shall also comply with all applicable requirements of the Exchange Act and the rules and regulations thereunder with respect to the matters set forth in this section 7. Nothing in this section 7 shall be deemed to affect any rights of shareholders to request inclusion of proposals in the Corporation’s proxy statement pursuant to Rule 14a-8 under the Exchange Act.

(6)           The Chairman of the Meeting shall, if the facts warrant, determine and declare at any meeting of the shareholders that business was not properly brought before the meeting of shareholders in accordance with the provisions of this section 7 of article II, and if he should so determine, he shall so declare to the meeting and any such business not properly brought before the meeting shall not be transacted.  A determination whether a matter is or is not properly before the meeting shall not depend on whether such proposal has been or will be included in any proxy statement delivered or to be delivered to the Corporation’s shareholders.

(7)           Nothing in this subsection (b) shall affect the rights of holders of the Corporation’s preferred stock as provided in section 3(b) of article 6 of the Corporation’s articles of incorporation or as provided in subsection (a) of section 4 of article II of these bylaws with respect to the rights of the Corporation’s preferred shareholders.
 
 
7

 

(c)           Nothing in subsection (b)(2) or (b)(6) of this section 7 shall apply to the following provisions of these bylaws or any proposal by a shareholder or shareholders with respect to any matter governed by and inconsistent with any of the following provisions:

Article II, section 8(a);
Article III, section 1(c);
Article III, section 1(e); and
Article XIII, section 2.

       Section 8.            Amendment of Articles of Incorporation.

(a)           Shareholder Proposals.  No proposal by a shareholder to amend or supplement the articles of incorporation of the Corporation shall be voted upon at a meeting of shareholders unless, at least 180 days before such meeting of shareholders, such shareholder shall have delivered in writing to the secretary of the Corporation (i) notice of such proposal, including all information required by section 7(b)(3) of article II of these bylaws, (ii) the text of such amendment or supplement and (iii) an opinion of counsel, which counsel and the form and substance of which opinion shall be reasonably satisfactory to the board of directors of the Corporation, to the effect that the articles of incorporation of the Corporation, as proposed to be so amended or supplemented, would not be in conflict with the laws of the State of Louisiana.  In no event shall any adjournment, postponement or deferral of a meeting of shareholders or the announcement thereof commence a new time period for the giving of a shareholder’s notice as described above.  Within 30 days after such shareholder shall have delivered the aforesaid items to the secretary of the Corporation, the secretary and the board of directors of the Corporation shall respectively determine whether the items to be ruled upon by them are reasonably satisfactory and shall notify such shareholder in writing of their respective determinations.  If such shareholder fails to submit a required item in the form or within the time indicated, or if the secretary or the board of directors of the Corporation determines that the items to be ruled upon by them are not reasonably satisfactory, then such proposal by such shareholder may not be voted upon by the shareholders of the Corporation at such meeting of shareholders.

(b)           Effectiveness.  No provision amending or supplementing, or purporting to amend or supplement, the articles of incorporation of the Corporation that would have an effect, direct or indirect, on any of the following items may be included in articles of amendment signed by any officer, agent or representative of the Corporation on behalf of the Corporation or delivered to the Secretary of State of Louisiana for filing of record until the later of (i) one year following the adoption by the shareholders of such amendment or supplement or (ii) 10 days after the adjournment sine die of the annual meeting of shareholders next succeeding the adoption by the shareholders of the Corporation of such amendment or supplement:

(1)           quorum at a regular or special meeting of shareholders;

(2)           procedures for amendment of the articles of incorporation or bylaws of the Corporation upon a proposal by a shareholder of the Corporation;
 
 
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(3)           the effective date of an amendment to the articles of incorporation or bylaws of the Corporation, or the time at which steps may be taken to effect an amendment to the articles of incorporation or bylaws of the Corporation; or

(4)           votes of shareholders of the Corporation required to approve (i) an amendment or supplement to or repeal of the bylaws of the Corporation, (ii) an amendment or supplement to the articles of incorporation of the Corporation, or (iii) a merger, consolidation, share exchange, reclassification of securities, repurchase of shares, transfer of all or substantially all of the assets of the Corporation, dissolution, “business combination” as defined in article X of these bylaws, or similar transaction.

Section 9.             Effectiveness of Other Amendments to Articles of Incorporation.  No provision amending or supplementing, or purporting to amend or supplement, the articles of incorporation of the Corporation that would have an effect, direct or indirect, on any of the following items may be included in articles of amendment signed by any officer, agent or representative of the Corporation on behalf of the Corporation or delivered to the Secretary of State of Louisiana for filing of record until the later of (i) one year following the adoption by the shareholders of such amendment or supplement or (ii) 10 days after the adjournment sine die of the annual meeting of the shareholders next succeeding the adoption by the shareholders of the Corporation of such amendment or supplement:

(1)           the number of directors of the Corporation;

(2)           the classification of the board of directors of the Corporation into three classes of as nearly as possible equal size;

(3)           the procedures for nomination by a shareholder of persons to be elected as directors of the Corporation;

(4)           qualifications of directors of the Corporation or the declaration by the board of directors of a vacancy in the office of director;

(5)           removal of directors or officer of the Corporation;

(6)           power of directors of the Corporation;

(7)           the filling of vacancies on the board of directors of the Corporation and the election of directors to fill newly created directorships;

(8)           powers of committees of the board of directors of the Corporation;

(9)           the calling of special meetings of shareholders;

(10)           determinations of the presiding person at a meeting of shareholders;
or
 
 
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(11)           votes of shareholders of the Corporation required to approve the removal of a director.

Section 10.           General.  As used in these bylaws, the term “shareholder” shall have the meaning given such term in Section 1 of the Louisiana Business Corporation Law.  As used in these bylaws, the terms “shares entitled to vote” and “votes entitled to be cast” shall mean (i) if a record date has been fixed for such meeting of shareholders, shares (or the votes related to such shares) of capital stock of the Corporation, which class or series of capital stock have the right to vote on such matter pursuant to the provisions of the articles of incorporation of the Corporation, outstanding as of the record date, or (ii) if a record date has not been fixed for such meeting of shareholders, shares (or the votes related to such shares) of capital stock of the Corporation, which class or series of capital stock have the right to vote on such matter pursuant to the provisions of the articles of incorporation of the Corporation, outstanding on the date of such meeting.

ARTICLE III
 
Directors

Section 1.             Certain General Provisions.

(a)           Number.  The corporate powers of the Corporation shall be vested in and exercised, and the business and affairs of the Corporation shall be managed, by a board of directors which shall consist of ten (10) directors.

(b)           Classification.  The board of directors of the Corporation shall be divided into three classes of as nearly as possible equal size, with the term of office of directors of one class expiring each year.  At the 2000 annual meeting of shareholders, the Class III directors shall be elected to hold office for a term expiring at the third succeeding annual meeting.  At the 2001 annual meeting of shareholders, the Class I directors shall be elected to hold office for a term expiring at the third succeeding annual meeting.  At the 2002 annual meeting of shareholders, the Class II directors shall be elected to hold office for a term expiring at the third succeeding annual meeting.  Thereafter, at each annual meeting of shareholders, the successors to the class of directors whose terms shall have expired at such meeting shall be elected to hold office for a term expiring at the third annual meeting succeeding such meeting.

(c)           Nominations.  Nominations for election of members of the board of directors may be made by the board of directors or by a shareholder.  The name of a person to be nominated by a shareholder (a “Nominator”) as a member of the board of directors of the Corporation must be submitted in writing to the secretary of the Corporation not fewer than 180 days before the date of the meeting of shareholders at which such person is proposed to be nominated.  The Nominator shall also submit written evidence, reasonably satisfactory to the secretary of the Corporation, that the Nominator is a shareholder and shall identify in writing the information required by section 7(b)(3) of article II of these bylaws, except that all information required to be provided with respect to any shareholder or beneficial owner shall also be provided with respect to each proposed nominee.  At such time, the Nominator shall also submit in writing (1) to the extent not provided in the information submitted pursuant to this subsection (c), (x) description of all direct and indirect
 
 
 
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compensation and other material monetary agreements, arrangements and understandings during the past three years, and any other material relationships, between or among the shareholder giving the notice and the beneficial owner, if any, on whose behalf the nomination is made, and their respective affiliates and associates, or others Acting in Concert (as defined below) therewith, on the one hand, and each proposed nominee, and his or her respective affiliates and associates, or others Acting in Concert therewith, on the other hand, including, without limitation, all information that would be required to be disclosed pursuant to Rule 404 promulgated under Regulation S-K if such shareholder and such beneficial owner, or any affiliate or associate thereof or person Acting in Concert therewith, were the “registrant” for purposes of such rule and the nominee were a director or executive officer of such registrant, (y) the name, age, business address and residence address, business experience or other qualifications of each such proposed nominee, (z) the principal occupation or employment of each such proposed nominee and (2) a notarized affidavit executed by each such proposed nominee to the effect (x) that, if elected as a member of the board of directors, he will serve, (y) that he has reviewed the provisions of section 1 of this article III of these bylaws, and (z) that he is eligible for election as a member of the board of directors.  In no event shall any adjournment, postponement or deferral of a meeting of shareholders or the announcement thereof commence a new time period for the giving of a shareholder’s notice as described above.  Within 30 days after the Nominator has submitted the aforesaid items to the secretary of the Corporation, the secretary of the Corporation shall determine whether the evidence of the Nominator’s status as a shareholder submitted by the Nominator is reasonably satisfactory and shall notify the Nominator in writing of his determination with respect thereto. The failure of the secretary of the Corporation to find such evidence reasonably satisfactory, or the failure of the Nominator to submit the requisite information in the form or within the time indicated, shall make the person to be nominated ineligible for nomination at the meeting of shareholders at which such person is proposed to be nominated. Beneficial ownership shall be determined in accordance with section 1 of article X of these bylaws.

To be eligible to be a nominee for election or reelection as a director of the Corporation, a person must deliver (in accordance with the time periods prescribed for delivery of notice set forth above) to the secretary of the Corporation at the principal executive offices of the Corporation a written questionnaire with respect to the background and qualification of such person and the background of any other person or entity on whose behalf the nomination is being made (which questionnaire shall be in the form provided by the secretary upon written request) and a written representation and agreement (in the form provided by the secretary upon written request) that such person (A) is not and will not become a party to (1) any agreement, arrangement or understanding with, and has not given any commitment or assurance to, any person or entity as to how such person, if elected as a director of the Corporation, will act or vote on any issue or question (a “Voting Commitment”) that has not been disclosed to the Corporation or (2) any Voting Commitment that could limit or interfere with such person’s ability to comply, if elected as a director of the Corporation, with such person’s fiduciary duties under applicable law, (B) is not and will not become a party to any agreement, arrangement or understanding with any person or entity other than the Corporation with respect to any direct or indirect compensation, reimbursement or indemnification in connection with service or action as a director that has not been disclosed therein, and (C) in such person’s individual capacity and on behalf of any person or entity on whose behalf the nomination is being made, would be in compliance, if elected as a director of the Corporation, and will comply with all applicable publicly disclosed corporate
 
 
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governance, conflict of interest, confidentiality and stock ownership and trading policies and guidelines of the Corporation.

           A person shall be deemed to be “Acting in Concert” with another person for purposes of these bylaws if such person knowingly acts (whether or not pursuant to an express agreement, arrangement or understanding) in concert with, or towards a common goal relating to the management, governance or control of the Corporation in parallel with, such other person where (A) each person is conscious of the other person’s conduct or intent and this awareness is an element in their decision-making processes and (B) at least one additional factor suggests that such persons intend to act in concert or in parallel, which such additional factors may include, without limitation, exchanging information (whether publicly or privately), attending meetings, conducting discussions, or making or soliciting invitations to act in concert or in parallel; provided, that a person shall not be deemed to be Acting in Concert with any other person solely as a result of the solicitation or receipt of revocable proxies or consents from such other person in response to a solicitation made pursuant to, and in accordance with, Section 14(a) of the Exchange Act by way of a proxy or consent solicitation statement filed on Schedule 14A.  A person Acting in Concert with another person shall be deemed to be Acting in Concert with any third party who is also Acting in Concert with such other person.

(d)         Qualifications; Declaration of Vacancy.

(1)           No person shall be eligible for election or reelection as a director after attaining age 72, and no person who is or shall have been a full-time officer or employee of the Corporation or any subsidiary thereof shall be eligible for election or reelection as a director after attaining age 65 or (even if under 65) after such director’s employment by the Corporation has terminated.

(2)           Upon attaining the age of 72 or 65, as specified in paragraph (1) immediately preceding, a director may continue to serve as a director of the Corporation until no later than the next succeeding annual meeting of shareholders, at which time, unless he has previously ceased to be a member of the board of directors of the Corporation, his position as a director shall cease.  Notwithstanding the foregoing, with regard to a director of the Corporation who is also an officer or employee of the Corporation or any subsidiary thereof, such director’s position as a director shall cease immediately upon termination of such director's employment by the Corporation.

(3)           No person shall be eligible for election or reelection or to continue to serve as a member of the board of directors who is an officer, director, agent, representative, partner, employee, or nominee of, or otherwise acting at the direction of, or Acting in Concert with, (y) a “public utility company” (other than one that is an “affiliate” of the Corporation) or “holding company” (other than one that is an “affiliate” of the Corporation) as such terms are defined in the Public Utility Holding Company Act of 1935, as amended, or “public utility” (other than one that is an “affiliate” (as defined in 18 C.F.R. §161.2) of the Corporation) as such term is defined in Section 201(e) of the Federal Power Act of 1920, as amended, or (z) an “affiliate” (as defined in 17 C.F.R. § 230.405) under the Securities Act of 1933, as amended) of any of the persons or entities specified in clause (y)
 
 
 
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immediately preceding.

(4)           Upon the occurrence of any of the events described in paragraph (2) of this subsection (d), the affected director shall cease to be a director of the Corporation at the time specified in such paragraph.  Determination of the eligibility of a person for election, reelection, or continued service on the board of directors under other provisions of this subsection (d) or otherwise as provided by applicable law including, but not limited to, occurrence of an event specified in Section 81.C(2) of the Louisiana Business Corporation Law, shall, subject to the provisions of paragraph (6) below, be made by vote of a majority of the members of the board of directors.  If the board of directors, pursuant to such a determination, determines that a person is ineligible for election, reelection, or continued service on the board of directors, such ineligibility shall be effective immediately upon such determination, and, if the affected person is a director of the Corporation at the time of such determination, his position as a director shall cease at such time.

Within 30 days after a Nominator has submitted the name of a person to be nominated as a member of the board of directors, the board of directors shall determine whether the proposed nominee is eligible for election under this subsection (d) and shall notify the Nominator in writing of its determination.  If the board of directors shall determine that such proposed nominee is not eligible for election, such person shall be ineligible to be nominated at the meeting of shareholders for which his nomination was proposed.

(5)           If a director of the Corporation ceases to be a director (x) at the annual meeting of shareholders next succeeding the day upon which he attained the age of 72 or 65, as specified in paragraphs (1), (2), and (4) of this subsection (d), and if there is time remaining in the regularly scheduled term of office of such director, (y) because of termination of employment, as provided in paragraphs (1), (2), and (4) of this subsection (d), or (z) upon the determination of the board of directors of the Corporation pursuant to paragraph (4) of this subsection (d) that a director of the Corporation is no longer qualified to continue serving as a director of the Corporation, the board of directors shall declare the office held by such director vacant and may fill such vacancy as provided in section 2 of this article III of these bylaws.

(6)           Without limiting the ability of the board of directors as provided by applicable law to declare vacant the position of a director on the board of directors, if a member of the board of directors has been adjudged by a court of competent jurisdiction to be guilty of fraud, criminal conduct (other than minor traffic violations), gross abuse of office amounting to a breach of trust, or similar misconduct, and no appeal (or further appeal) therefrom is permitted under applicable law, the other directors then in office, by unanimous vote, may declare the position occupied by such director vacant, and such other directors may fill such vacancy as provided in section 2 of this article III of these bylaws.

(e)           Removal.  In this subsection (e), the terms “remove” and “removal” and their related grammatical forms shall refer only to the process of dismissal provided for in this subsection, and shall not be deemed to refer to disqualification of a director, cessation of a director
 
 
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to be such, or declaration of a vacancy in the office of director as provided for in subsection (d) of this section 1 or otherwise as permitted by law.

A member of the board of directors may be removed by the shareholders of the Corporation only for cause.  Any such removal for cause shall be at a special meeting of shareholders called for such purpose.  The vote of the holders of shares conferring 80% of the total votes of all shares of capital stock of the Corporation voting as a single class shall be necessary to remove a director; provided, however, that if a director has been elected by the exercise of the privilege of cumulative voting, such director may not be removed if the votes cast against his removal would be sufficient to elect him if then cumulatively voted at an election of the class of directors of which he is a part.  For purposes of this subsection (e), cause for removal shall exist only if a director shall have been adjudged by a court of competent jurisdiction to be guilty of fraud, criminal conduct (other than minor traffic violations), gross abuse of office amounting to a breach of trust, or similar misconduct, and no appeal (or further appeal) therefrom shall be permitted under applicable law.

No proposal by a shareholder to remove a director of the Corporation shall be voted upon at a meeting of shareholders unless, at least 180 days before such meeting, such shareholder shall have delivered in writing to the secretary of the Corporation (1) notice of such proposal, including all information required by section 7(b)(3) of article II of these bylaws, (2) a statement of the grounds on which such director is proposed to be removed and (3) an opinion of counsel, which counsel and the form and substance of which opinion shall be reasonably satisfactory to the board of directors of the Corporation (excluding the director proposed to be removed), to the effect that, if adopted at a duly called special meeting of the shareholders of the Corporation by the vote of the holders of shares conferring 80% of the total votes of all shares of the capital stock of the Corporation voting as single class, such removal would not be in conflict with the laws of the State of Louisiana, the articles of incorporation of the Corporation, or these bylaws.  In no event shall any adjournment, postponement or deferral of a special meeting of shareholders or the announcement thereof commence a new time period for the giving of a shareholder’s notice as described above.  Within 30 days after such shareholder shall have delivered the aforesaid items to the secretary of the Corporation, the secretary and the board of directors of the Corporation shall respectively determine whether the items to be ruled upon by them are reasonably satisfactory and shall notify such shareholder in writing of their respective determinations.  If such shareholder fails to submit a required item in the form or within the time indicated, or if the secretary or the board of directors of the Corporation determines that the items to be ruled upon by them, respectively, as provided above are not reasonably satisfactory, then such proposal by such shareholder may not be voted upon by the shareholders of the Corporation at such meeting of shareholders.

(f)           Powers.  Subject to the provisions of the laws of the State of Louisiana, the articles of incorporation of the Corporation, and these bylaws, the board of directors shall have and exercise, in addition to such powers as are set forth in the articles of incorporation, all of the powers which may be exercised by the Corporation, including, but without thereby limiting the generality of the above, the power to create and to delegate, with power to subdelegate, any of its powers to any committee, officer, or agent; provided, however, that the board of directors shall not have the power to delegate its authority to:
 
 
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(1)           amend, repeal, or supplement the bylaws of the Corporation;
 
(2)           take definitive action on a merger, consolidation, reclassification or exchange of securities, repurchase by the Corporation of any of its equity securities, transfer of all or substantially all of the assets of the Corporation, dissolution, "business combination" as defined in article X of these bylaws, or similar action;

(3)           elect or remove a director or officer of the Corporation;

(4)           submit a proposal to shareholders for action by shareholders;

(5)           appoint a director to or remove a director from a committee of the board of directors; or

(6)           declare a dividend on the capital stock of the Corporation.

(g)           Change in Number of Directors. No amendment or supplement to or repeal of subsection (a) of section 1 of article III of these bylaws that would have the effect of increasing the number of authorized directors of the Corporation by more than two during any 12-month period shall be permitted unless at least 80% of the “continuing directors” then in office (as defined in subsection (b) of section 2 of article II of these bylaws) shall authorize such action.  If the number of directorships is changed for any reason, any increase or decrease in the number of directorships shall be apportioned among the classes so as to make all classes as nearly equal in number as possible.

(h)           Rights of Preferred Shareholders, etc.  Nothing in this section 1 of this article III of these bylaws shall affect the rights of the Corporation's shareholders as provided in section 3(b) of article 6 of the Corporation's articles of incorporation.

Section 2.             Filling of Vacancies.  Except to the extent required by law or section 3(b) of article 6 of the articles of incorporation of the Corporation, newly created directorships resulting from any increase in the authorized number of directors and any vacancies in the board of directors resulting from the attainment by a director of the age of 72 or 65, as specified in paragraphs (1), (2), (4), and (5) of subsection (d) of section 1 of this article III, or from death, resignation, disqualification or removal of a director, or from failure of the shareholders to elect the full number of authorized directors, or from any other cause shall be filled by the affirmative vote of at least a majority of the remaining directors (or director) then in office, even though less than a quorum of the whole board.  Any director elected in accordance with the preceding sentence shall hold office for the remainder of the full term of the class of directors in which the new directorship was created or the vacancy occurred.  Except to the extent required by law or section 3(b) of article 6 of the articles of incorporation of the Corporation, the shareholders shall have no right to fill any vacancies in the board of directors.

Section 3.             Annual and Regular Meetings.  Within 45 days after each annual meeting of shareholders, and if possible on the date of each annual meeting of shareholders immediately
 
 
 
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following each such meeting, the board of directors shall hold an annual meeting for the purpose of electing officers and transacting other corporate business.  Such meeting shall be called in the manner for calling regular or special meetings of the board of directors.

Except as otherwise provided by resolution of the board of directors, other regular meetings of the board of directors shall be held on the last Friday in January, July and October at such places as the chief executive officer or president may direct in the notices of such meetings. At least five days’ notice by mail or written telecommunication shall be given to each director of the time and place of holding each regular meeting of the board of directors.

Section 4.             Special Meetings.  A special meeting of the board of directors may be called by the chief executive officer or president, to be held at such place as he may direct in the notice of such meeting, on four days’ notice by mail or three days’ notice by written telecommunication, to each director.  A special meeting shall be called by the chief executive officer or president in like manner on the written request of at least 50% of the members of the board.

Section 5.             Place of Meetings; Telephone Meetings. A meeting of the board of directors may be held either within or without the State of Louisiana.  The time and place of holding a regular or special meeting of the board of directors may be changed and another place and time fixed for such regular or special meeting by a majority of the members of the board.

The members of the board of directors, and a committee thereof, may participate in and hold a meeting of the board or of such committee by means of conference telephone or similar communications equipment provided that all persons participating in such meeting can hear and communicate with one another.  Participation in a meeting pursuant to this provision shall constitute presence in person at such meeting, except where a person participates in such meeting for the express purpose of objecting to the transaction of any business on the grounds that such meeting was not lawfully called or convened.

Section 6.             Quorum. A majority of the directors shall constitute a quorum, but a smaller number may adjourn a meeting from time to time without further notice until a quorum is secured.  If a quorum is present, the directors present can continue to do business until adjournment notwithstanding the subsequent withdrawal of enough directors to leave less than a quorum or the refusal of any director present to vote.

Section 7.             Compensation.  Each director shall be entitled to receive from the Corporation reimbursement of his expenses incurred in attending any regular or special meeting of the board and, by resolution of the board, such other compensation as it may approve.  Such reimbursement and compensation shall be payable whether or not an adjournment be had because of the absence of a quorum.  Nothing herein contained shall be construed to preclude any director from serving the Corporation in another capacity and receiving compensation therefor.

Section 8.             Committees.  From time to time, the board of directors may appoint, from its own number, in addition to the committees provided for in these bylaws, such other committee or committees for such purpose or purposes as it shall determine. Subject to the limitations imposed by these bylaws, the articles of incorporation, and the laws of the State of Louisiana, each
 
 
 
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committee of the board of directors shall have such powers as shall be specified in the resolution of appointment.

ARTICLE IV
 
Indemnification

Section 1.             Right to Indemnification - General.  The Corporation shall indemnify any person who was or is, or is threatened to be made, a party to or otherwise involved in any pending or completed action, suit, arbitration, alternate dispute resolution mechanism, investigation, administrative hearing or other proceeding, whether civil, criminal, administrative or investigative (any such threatened, pending or completed proceeding being hereinafter called a “Proceeding”) by reason of the fact that he is or was a director, officer, employee or agent of the Corporation or is or was serving at the request of the Corporation as a director, officer, employee or agent of another business, foreign or nonprofit corporation, partnership, joint venture, trust, employee benefit plan or other enterprise (whether the basis of his involvement in such Proceeding is alleged action in an official capacity or in any other capacity while serving as such), to the fullest extent permitted by applicable law in effect from time to time, and to such greater extent as applicable law may from time to time permit, from and against expenses, including attorney’s fees, judgments, fines, amounts paid or to be paid in settlement, liability and loss, ERISA excise taxes, actually and reasonably incurred by him or on his behalf or suffered in connection with such Proceeding or any claim, issue or matter therein; provided, however, that, except as provided in section 5 of this article, the Corporation shall indemnify any such person claiming indemnity in connection with a Proceeding initiated by such person only if such Proceeding was authorized by the board of directors.

 
Section 2.
Certain Provisions Respecting Indemnification for and Advancement of Expenses.

(a)           To the extent that a person referred to in section 1 of this article is required to serve as a witness in any Proceeding referred to therein, he shall be indemnified against all Expenses (as hereinafter defined) actually and reasonably incurred by him or on his behalf in connection with serving as a witness.

(b)           The Corporation shall from time to time pay, in advance of final disposition, all Expenses incurred by or on behalf of any person referred to in section 1 of this article claiming indemnity thereunder in respect of any Proceeding referred to therein.  Each such advance shall be made within ten days after the receipt by the Corporation of a statement from the claimant requesting the advance, which statement shall reasonably evidence the relevant Expenses and be accompanied or preceded by any such undertaking as may be required by applicable law respecting the contingent repayment of such Expenses.  Whenever and to the extent applicable law requires the board of directors to act in the specific case with respect to the payment of Expenses in advance of the final disposition of any Proceeding, the board of directors shall act with respect thereto within the period specified in the preceding sentence and shall withhold the payment of Expenses in advance only if there is a reasonable and prompt determination by the board of directors by a majority vote of a quorum of Disinterested Directors (as hereinafter defined), or (if
 
 
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such quorum is not obtainable or, even if obtainable, a quorum of Disinterested Directors so directs) by Independent Counsel (as hereinafter defined) in a written opinion, that advancement  of Expenses is inappropriate, even taking into account any undertaking given with respect to the repayment of such Expenses, because based on the facts then known there is no reasonable likelihood that the claimant would be able ultimately to demonstrate that he met the standard of conduct necessary for indemnification with respect to such Expenses.

Section 3.             Procedure for Determination of Entitlement to Indemnification.

(a)           To obtain indemnification under this article, a claimant shall submit to the Corporation a written application. The secretary of the Corporation shall, promptly upon receipt of such an application for indemnification, advise the board of directors in writing of the application. In connection with any such application, the claimant shall provide such documentation and information as is reasonably requested by the Corporation and reasonably available to him and relevant to a determination of entitlement to indemnification.

(b)           A person’s entitlement to indemnification under this article, unless ordered by a court, shall be determined, as required or permitted by applicable law: (i) by the board of directors by a majority vote of a quorum consisting of Disinterested Directors, (ii) if a quorum of the board of directors consisting of Disinterested Directors is not obtainable or, even if obtainable, a quorum of Disinterested Directors so directs, by Independent Counsel in a written opinion, or (iii) by the shareholders of the Corporation; provided, however, that if a Change of Control (as hereinafter defined) shall have occurred, no determination of entitlement to indemnification adverse to the claimant shall be made other than one made or concurred in by Independent Counsel, selected as provided in paragraph (d) of this section, in a written opinion.

(c)           If the determination of entitlement to indemnification is to be made by Independent Counsel in the absence of a Change of Control, the Corporation shall furnish notice to the claimant within ten days after receipt of the application for indemnification specifying the identity and address of Independent Counsel.  The claimant may, within fourteen days after receipt of such written notice of selection, deliver to the Corporation a written objection to such selection, subject to paragraph (e) of this section.  If such an objection is made, either the Corporation or the claimant may petition any court of competent jurisdiction for a determination that the objection has no reasonable basis or for the appointment as Independent Counsel of counsel selected by the court.

(d)           If there has been a Change of Control, Independent Counsel to act as and to the extent required by paragraph (b) of this section or paragraph (b) of section 2 shall be selected by the claimant, who shall give the Corporation written notice advising of the identity and address of the Independent Counsel so selected.  The Corporation may, within seven days after receipt of such written notice of selection, deliver to the claimant a written objection to such selection, subject to paragraph (e) of this section.  The claimant may, within five days after the receipt of such objection, select other counsel to act as Independent Counsel, and the Corporation may, within seven days after receipt of such written notice of selection, deliver to the claimant a written objection, as aforesaid, to such second selection.  In the case of any such objection the claimant may petition any court of competent jurisdiction for a determination that the objection has no
 
 
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reasonable basis or for the appointment as Independent Counsel of counsel selected by the court.

(e) Any objection to the selection of Independent Counsel may be asserted only on the ground that the counsel so selected does not qualify as Independent Counsel under the definition contained in section 7 of this article, and the objection shall set forth with particularity the basis of such assertion.  No counsel selected by the Corporation or by the claimant may serve as Independent Counsel if a timely objection has been made to his selection unless a court has determined that such objection has no reasonable basis.
 
(f) The Corporation shall pay any and all reasonable fees and expenses of Independent Counsel acting pursuant to this article and in any proceeding in which such counsel is a party or a witness in respect of its investigation and report.  The Corporation shall pay all reasonable fees and expenses incident to the procedures of this section regardless of the manner in which Independent Counsel is selected or appointed.

Section 4.             Presumptions and Effect of Certain Proceedings.

(a)           A person referred to in section 1 of this article claiming a right to indemnification under this article shall be presumed (except as may be otherwise expressly provided in this article or required by applicable law) to be entitled to such indemnification upon submission of an application for indemnification in accordance with section 3, and the Corporation shall have the burden of proof to overcome the presumption in any determination contrary to the presumption.

(b)           Unless the determination is to be made by Independent Counsel, if the person or persons empowered under section 3 of this article to determine entitlement to indemnification shall not have made and furnished the determination in writing to the claimant within 60 days after receipt by the Corporation of the application for indemnification, the determination of entitlement to indemnification shall be deemed to have been made in favor of the claimant unless the claimant knowingly misrepresented a material fact in connection with the application or such indemnification is prohibited by law. The termination of any Proceeding, or of any claim, issue or matter therein, by judgment, order, settlement or conviction, or upon a plea of nolo contender or its equivalent, shall not of itself adversely affect the right of a claimant to indemnification or create a presumption that a claimant did not act in a manner which would deny him the right to indemnification.

Section 5.             Right of Claimant to Bring Suit.

(a)           If (i) a determination is made pursuant to the procedures contemplated by section 3 of this article that a claimant is not entitled to indemnification under this article, (ii)  advancement of Expenses is not timely made pursuant to paragraph (b) of section 2 of this article, (iii) Independent Counsel has not made and delivered a written opinion as to entitlement to indemnification within 90 days after the selection or appointment of counsel has become final by virtue of the lapse of time for objection or the overruling of objections or appointment of counsel by a court, or (iv) payment of a claim for indemnification is not made within five days after a favorable determination of entitlement to indemnification has been made or deemed to have been made pursuant to section 3 or 4 of this article, the claimant shall be entitled to bring suit against the
 
 
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Corporation to establish his entitlement to such indemnification or advancement of Expenses and to recover the unpaid amount of his claim. It shall be a defense to any such action (other than an action brought to enforce a claim for Expenses incurred in defending any Proceeding in  advance of its final disposition where the required undertaking, if any is required, has been tendered to the Corporation) that the claimant did not meet the applicable standard of conduct which makes it permissible for the Corporation to indemnify the claimant for the amount claimed, but the burden of proving such defense shall be upon the Corporation.  Neither the failure of the Corporation (including its board of directors, Independent Counsel or its shareholders) to have made a determination before the commencement of such action that indemnification of the claimant is proper under the circumstances because he has met such applicable standard of conduct, nor an actual determination by the Corporation (including its board of directors, Independent Counsel or its shareholders) that the claimant has not met the applicable standard of conduct, shall be a defense to the action or create a presumption that the claimant has not met the applicable standard of conduct, and the claimant shall be entitled to a de novo trial on the merits as to any such matter as to which no determination or an adverse determination has been made.

(b)           If a claimant is successful in whole or in part in prosecuting any claim referred to in paragraph (a) of this section, the claimant shall also be entitled to recover from the Corporation, and shall be indemnified by the Corporation against, any and all Expenses actually and reasonably incurred by him in prosecuting such claim.
 
Section 6.             Non-Exclusivity and Survival of Rights.  The rights of indemnification and to receive advancement of Expenses contemplated by this article shall not be deemed exclusive of any other rights to which any person may at any time be entitled under any bylaw, agreement, authorization of shareholders or directors (regardless of whether directors authorizing such indemnification are beneficiaries thereof), or otherwise, both as to action in his official capacity and as to action in another capacity; provided that no other indemnification measure shall permit indemnification of any person for the results of such person's willful or intentional misconduct.

The Corporation may procure or maintain insurance or other similar arrangement, at its expense, to protect itself and any director, officer, employee or agent of the Corporation or other corporation, partnership, joint venture, trust or other enterprise against any expense, liability or loss asserted against or incurred by such person, whether or not the Corporation would have the power to indemnify such person against such expense or liability.

In considering the cost and availability of such insurance, the Corporation, in the exercise of its business judgment, may purchase insurance which provides for any and all of (i) deductibles, (ii) limits on payments required to be made by the insurer, or (iii) coverage which may not be as comprehensive as that previously included in insurance purchased by the Corporation. The purchase of insurance with deductibles, limits on payments and coverage exclusions will be deemed to be in the best interest of the Corporation but may not be in the best interest of certain of the persons covered thereby.  As to the Corporation, purchasing insurance with deductibles, limits on payments, and coverage exclusions is similar to the Corporation’s practice of self-insurance in other areas.  In order to protect the officers and directors of the Corporation, the Corporation shall indemnify and hold each of them harmless as provided in section 1 of this article IV, without regard to whether the Corporation would otherwise be entitled to indemnify such officer or
 
 
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director under the other provisions of this article IV, to the extent  (i) of such deductibles, (ii) of amounts exceeding payments required to be made by an insurer or (iii) that prior policies of officers and directors liability insurance held by the Corporation would have provided for payment to such officer or director.  Notwithstanding the foregoing provisions of this section 6, no person shall be entitled to indemnification for the results of such person's willful or intentional misconduct.

The right to indemnification conferred in this article shall be a contract right, and no amendment, alteration or repeal of this article or any provision thereof shall restrict the indemnification rights granted by this article as to any person claiming indemnification with respect to acts, events and circumstances that occurred, in whole or in part, before such amendment, alteration or repeal.  The provisions of this article shall continue as to a person who has ceased to be a director, officer, employee or agent and shall inure to the benefit of his heirs, executors and legal representatives.

    Section 7.            Definitions. For purposes of this article:

(a)           “Change of Control” means the occurrence of any of the following events or circumstances: (1) there shall have occurred an event required to be reported in response to Item 6(e) of Schedule 14A of Regulation 14A (or in response to any similar item on any similar schedule or form) promulgated under the Exchange Act, whether or not the Corporation is then subject to such reporting requirement; (2) (i) any “person” (as such term is used in Section 13(d) and 14(d) of the Exchange Act) shall have become the “beneficial owner”, (as defined in Rule 13d-3 under the Exchange Act), directly or indirectly, of securities of the Corporation representing 30% or more of the combined voting power of the Corporation’s then outstanding voting securities without the prior approval of at least two-thirds of the members of the board of directors in office immediately before such person’s attaining such percentage interest; (3) the Corporation is a party to a merger, consolidation, sale of assets or other reorganization, or the subject of a proxy contest, as a consequence of which members of the board of directors in office immediately before such transaction or event constitute less than a majority of the board of directors thereafter; (4) during any period of two consecutive years, individuals who at the beginning of such period constituted the board of directors (including for this purpose any new director whose election or nomination for election by the Corporation’s shareholders was approved by a vote of at least two-thirds of the directors then still in office who were directors at the beginning of such period) cease for any reason to constitute at least a majority of the board of directors.

(b)           “Disinterested Director” means a director of the Corporation who is not and was not a party to the Proceeding in respect of which indemnification is sought as provided in this article.

(c)           “Expenses” shall include all reasonable attorneys’ fees, retainers, court costs, transcript costs, fees of experts, witness fees, travel expenses, duplicating costs, printing and binding costs, telephone charges, postage, delivery service fees, and all other disbursements or expenses of the types customarily incurred in connection with prosecuting, defending, preparing to prosecute or defend, investigating, or being or preparing to be a witness in a Proceeding.

(d)           “Independent Counsel” means a law firm, or a member of a law firm, with
 
 
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substantial experience in matters of corporation law that neither presently is, nor in the five years before his selection or appointment has been, retained to represent: (i) the Corporation or person claiming indemnification in any matter material to either, or (ii) any other party to the Proceeding giving rise to a claim for indemnification hereunder, and is not otherwise precluded under applicable professional standards from acting in the capacity herein contemplated.

ARTICLE V
 
Executive Committee

Section 1.             Election and Tenure.  The board of directors may appoint an executive committee consisting of such number of directors as it may appoint, to serve at the pleasure of the board of directors, but in any event not beyond the next annual meeting of the board of directors.  The board may at any time, without notice, remove and replace any member of the executive committee.

Section 2.             Executive Committee.  Subject to the provisions of subsection (f) of section 1 of article III of these bylaws, the executive committee shall have a charter that will be approved, and revised as appropriate, from time to time by the committee and the board.  In general terms, the functions of the committee shall be those as set forth in the charter.

Section 3.             Meetings.  The executive committee shall meet at stated times or on notice to all by one of its number, in which notice the time and place of the meeting shall be set forth.  The executive committee shall fix its own rules of procedure, and a majority shall constitute a quorum; but the affirmative vote of a majority of the whole committee shall be necessary in every case.  The executive committee shall keep regular minutes of its proceedings and report the same to the board of directors.

Section 4.             Compensation.  Members of the executive committee, other than officers of the Corporation, shall receive such compensation for their services as shall be prescribed by the board of directors.  Each member of the executive committee shall be entitled to receive from the Corporation reimbursement of his expenses incurred in attending a meeting of such committee.

ARTICLE VI
 
Audit Committee

Section 1.             Election and Tenure.  The board of directors may appoint an audit committee, consisting of such number of directors as it may appoint, to serve at the pleasure of the board of directors, but in any event not beyond the next annual meeting of the board of directors.  The board may at any time, without notice, remove and replace any member of the audit committee.

Section 2.             Audit Committee.  Subject to the provisions of subsection (f) of section 1 of article III of these bylaws, the audit committee shall have a charter that will be approved, and revised as appropriate, from time to time by the committee and the board.  In general terms, the
 
 
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functions of the committee shall be those as set forth in the charter.

Section 3.             Meetings.  The audit committee shall meet at stated times or on notice to all by one of its number, in which notice the time and place of the meeting shall be set forth.  The audit committee shall fix its own rules of procedure, and a majority shall constitute a quorum; but the affirmative vote of a majority of the whole committee shall be necessary in every case.  The audit committee shall keep regular minutes of its proceedings and report the same to the board of directors.

Section 4.             Compensation.  Members of the audit committee, other than officers of the Corporation, shall receive such compensation for their services as shall be prescribed by the board of directors.  Each member of the audit committee shall be entitled to receive from the Corporation reimbursement of his expenses incurred in attending a meeting of the audit committee.

ARTICLE VII
 
Compensation Committee

Section 1.             Election and Tenure.  The board of directors may appoint a compensation committee, consisting of such number of directors as it may appoint, to serve at the pleasure of the board of directors, but in any event not beyond the next annual meeting of the board of directors. The board may at any time, without notice, remove and replace any member of the compensation committee.

Section 2.             Compensation Committee.  Subject to the provisions of subsection (f) of section 1 of article III of these bylaws, the compensation committee shall have a charter that will be approved, and revised as appropriate, from time to time by the committee and the board.  In general terms, the functions of the committee shall be those as set forth in the charter.

Section 3.             Meetings.  The compensation committee shall meet at stated times or on notice to all by one of its number, in which notice the time and place of the meeting shall be set forth. The compensation committee shall fix its own rules of procedure, and a majority shall constitute a quorum; but the affirmative vote of the majority of the whole committee shall be necessary in every case. The compensation committee shall keep regular minutes of its proceedings and report the same to the board of directors.

Section 4.             Compensation.  Members of the compensation committee, other than officers of the Corporation, shall receive such compensation for their services as shall be prescribed by the board of directors.  Each member of the compensation committee shall be entitled to receive from the Corporation reimbursement of his expenses incurred in attending a meeting of the compensation committee.

 
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Article VII.A.

Nominating/Governance Committee

Section 1.             Election and Tenure.  The board of directors may appoint a nominating/governance committee consisting of such number of directors as it may appoint, to serve at the pleasure of the board of directors, but in any event not beyond the next annual meeting of the board of directors.  The board may at anytime, without notice remove and replace any member of the nominating/governance committee.

Section 2.             Nominating/Governance Committee.  Subject to the provisions of subsection (f) of section 1 of article III of these bylaws, the nominating/governance committee shall have a charter that will be approved, and revised as appropriate, from time to time by the committee and the board.  In general terms, the functions of the committee shall be those as set forth in the charter.

Section 3.             Meetings.  The nominating/governance committee shall meet at stated times or on notice to all by one of its number, in which notice the time and place of the meeting shall be set forth.  The nominating/governance committee shall fix its own rules of procedure, and a majority shall constitute a quorum; but the affirmative vote of a majority of the whole committee shall be necessary in every case.  The nominating/governance committee shall keep regular minutes of its proceedings and report the same to the board of directors.

Section 4.             Compensation.  Members of the nominating/governance committee, other than officers of the Corporation, shall receive such compensation for their services as shall be prescribed by the board of directors.  Each member of the nominating/governance committee shall be entitled to receive from the Corporation reimbursement of his expenses incurred in attending a meeting of such committee.


ARTICLE VIII
 
Officers

Section l.              Election, Tenure, and Compensation.  The officers of the Corporation shall consist of a president, one or more vice presidents, a secretary, a treasurer, and such other officers, including a chairman of the board of directors, as may from time to time be elected or appointed by the board of directors. Officers of the Corporation shall be elected annually by the board of directors as provided in section 3 of article III of these bylaws.  If such annual election is not held, the officers then in office shall remain as such until their respective successors shall be elected and qualify.  No officer, except the chairman of the board of directors, need be a director, and any two or more offices, except the offices of president and vice president, may be held by one person.  The powers of all officers of the Corporation shall be subject to the provisions of subsection (f) of section 1 of article III of these bylaws.

 
 
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Section 2.             Powers and Duties of Chairman of Board of Directors.  The board of directors may elect a non-employee chairman to give leadership to the board and to serve as liaison between management and the board of directors.  In collaboration with the chief executive officer, the chairman will establish an agenda for each board meeting which covers all matters which should come before the board in the proper exercise of its duties.  The chairman will be accountable and will provide leadership for all issues of corporate governance which should come to the attention of the board and its committees.  The chairman will provide leadership to the board in the establishment of positions which the board should take on issues to come before the annual meeting of shareholders.  The chairman shall perform such other duties as from time to time may be delegated to him/her by the board of directors.

Section 3.                  Powers and Duties of President.  The president shall be the chief executive officer and/or the chief operating officer of the Corporation and, subject to the direction of the board of directors, shall (a) have general and active management of the administration and operation of the business of the Corporation, (b) have the general supervision and direction of the other officers of the Corporation and shall see that their duties are properly performed, (c) see that all orders and resolutions of the board of directors are carried into effect, (d) have the power to execute contracts and conveyances on behalf of the Corporation (including without limitation conveyances of real and personal property to and by the Corporation), and (e) perform such other functions normally performed by a chief executive officer.

Section 4.             Powers and Duties of Vice President.  The board of directors may appoint one or more vice presidents.  Each vice president shall have the power to execute contracts and conveyances on behalf of the Corporation, and shall have such other powers and shall perform such other duties as may be assigned to him by the board of directors or by the president.

Section 5.             Powers and Duties of Secretary.  The secretary shall attend and record, in a book kept for such purpose, the proceedings of all meetings of the shareholders of the Corporation and of the board of directors.  He shall keep an account of stock registered and transferred in such manner as the board of directors may prescribe.  He shall keep the seal of the Corporation and, when authorized by the board of directors or the executive committee, he shall affix the seal of the Corporation to any instrument requiring the same, and attest the same by his signature, or cause the same to be attested by the signature of an assistant secretary.  He shall give proper notice of meetings of shareholders and directors and shall perform such other duties as shall be assigned to him.  Assistant secretaries shall have such duties as the board of directors may from time to time prescribe.

Section 6.             Powers and Duties of Treasurer.  The treasurer shall have custody of the funds and securities of the Corporation, shall keep full and accurate accounts of receipts and disbursements in books belonging to the Corporation, and shall deposit or cause to be deposited all moneys and other valuable effects in the name and to the credit of the Corporation in such depositories as may be designated by the board of directors.  He shall disburse or cause to be disbursed the funds of the Corporation as may be ordered by the board of directors, executive committee, chief executive officer or president, taking proper vouchers for such disbursements, and shall render to the chief executive officer, the president, and the directors at the regular meetings of the board of directors, or whenever they require it, an account of all his transactions as
 
 
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treasurer and of the financial condition of the Corporation, and at the regular meeting of the board of directors next preceding the annual shareholders’ meeting, a like report for the preceding fiscal year.  He shall give the Corporation a bond, if required by the board of directors, in such sum and in form and with security satisfactory to the board of directors, for the faithful performance of the duties of his office and the restoration to the Corporation, in case of his death, resignation, or removal from office, of all books, papers, vouchers, moneys, and other property of whatever kind in his possession belonging to the Corporation.  He shall perform such other duties as the board of directors or executive committee may from time to time prescribe.  Assistant treasurers shall have such duties as the board of directors may from time to time prescribe.

Section 7.             Delegation of Duties.  In case of the absence or disability of any officer of the Corporation, or for any other reason deemed sufficient by the board of directors, the board of directors may delegate such officer’s powers or duties for the time being to any other officer, to any employee with management responsibility, or to any director.

ARTICLE IX
 
Capital Stock

Section l.              Stock Certificates.  The shares of capital stock of the Corporation may be represented by certificates in such form as may be approved by the board of directors, which certificates shall be signed by the chief executive officer, the president or one of the vice presidents of the Corporation and also by the secretary or an assistant secretary, or the treasurer or an assistant treasurer.  Such certificates shall have affixed an impression of the seal of the Corporation.  Where such certificates are countersigned by a transfer agent and by a registrar, both of which may be the same institution, the signatures of such officers and the seal of the Corporation thereon may be facsimiles, engraved or printed.  If an officer of the Corporation who shall have signed a certificate of capital stock, or whose facsimile signature has been affixed for such purpose, shall cease to be such officer of the Corporation before the stock certificate so signed shall have been issued by the Corporation, such stock certificate may nevertheless be issued and delivered with the same force and effect as though the person who signed such certificate or whose facsimile signature has been affixed for such purpose had not ceased to be such officer of the Corporation.  Notwithstanding the foregoing regarding share certificates, officers of the Corporation may provide that some or all of any or all classes or series of the Corporation’s capital stock may be uncertificated shares.

Section 2.             Lost or Destroyed Certificates.  The board of directors may determine the conditions upon which a new certificate for capital stock of the Corporation may be issued in place of a certificate which is alleged to have been lost, stolen, or destroyed and may, in its discretion, require the owner of such certificate or his legal representative to give bond with sufficient surety to the Corporation to indemnify it against any loss or claim which may arise by reason of the issue of a new certificate in the place of the one so alleged to have been lost, stolen, or destroyed.

Section 3.             Transfer of Shares.  The shares of capital stock of the Corporation shall be transferable only upon its books by the holders thereof in person or by their duly authorized attorneys or legal representatives, and upon such transfer the old certificates, if such shares are
 
 
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represented by certificates, shall be surrendered to the Corporation by the delivery thereof to the person in charge of the stock or transfer books and ledgers, or to such other person as the board of directors may designate, by whom they shall be canceled.  New stock certificates or uncertificated shares may thereupon be issued, representing the shares so transferred.  A record shall be made of each transfer.

Section 4.             Dividends.  Dividends upon the capital stock may be declared by the board of directors at a regular or special meeting out of the net profits or surplus of the Corporation.  Before paying a dividend or making a distribution of profits, there may be set aside out of the accumulated profits of the Corporation such sum or sums as the directors from time to time, in their absolute discretion, think proper as a reserve fund for meeting contingencies or for equalizing dividends or for repairing or maintaining property of the Corporation or for such other purpose as the directors shall think conducive to the interests of the Corporation.

Section 5.             Closing Transfer Books; Fixing Record Date.  The board of directors may fix the time, not exceeding 60 days preceding the date of a meeting of shareholders, a dividend payment date, or a date for the allotment of rights, during which the books of the Corporation shall be temporarily closed against transfers of stock; or, in lieu thereof, the board of directors may fix a date, not exceeding 60 days preceding the date of a meeting of shareholders, a dividend payment date, or a date for the allotment of rights, as a date for the taking of a record of the shareholders entitled to notice of and to vote at such meeting, or entitled to receive such dividends or such rights, as the case may be; and only shareholders of record on such date shall be entitled to notice of and to vote at such meeting, or to receive such dividends or rights, as the case may be.

ARTICLE X
 
Fair-Price Provisions

Section 1.             Definitions.  As used in article X of these bylaws, the following terms shall have the indicated meanings:

(a)           “Affiliate,” including the term “affiliated person,” means a person that directly or indirectly through one or more intermediaries controls, is controlled by, or is under common control with, a specified person.

(b)           “Associate,” when used to indicate a relationship with any person, means any of the following:

(1)           A corporation or organization, other than the Corporation or a subsidiary of the Corporation, of which such person is an officer, director, or partner or is, directly or indirectly, the beneficial owner of 10% or more of any class or series of equity securities.

(2)           A trust or other estate on which such person has a substantial beneficial interest or as to which such person serves as trustee or in a similar fiduciary capacity.

(3)           A relative or spouse of such person, or any relative of such spouse, who has
 
 
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the same home as such person or who is a director or officer of the Corporation or any of its affiliates.

(c)           “Beneficial owner,” when used with respect to voting stock, means any of the following:
(1)           A person who individually or with any of his affiliates or associates beneficially owns voting stock, directly or indirectly.

(2)           A person who individually or with any of his affiliates or associates has either of the following rights:

(A)           To acquire voting stock, whether such right is exercisable immediately or only after the passage of time, pursuant to any agreement, arrangement, or understanding or upon the exercise of conversion rights, exchange rights, warrants, or options, or otherwise.

(B)           To vote voting stock pursuant to any agreement, arrangement, or understanding.

(3)           A person who has any agreement, arrangement, or understanding for the purpose of acquiring, holding, voting, or disposing voting stock with any other person who beneficially owns or whose affiliates beneficially own, directly or indirectly, such shares of voting stock.

(d)           “Business combination” means any of the following:

(1)           Except for a merger, consolidation, or share exchange that does not alter the contract rights of the stock as expressly set forth in the articles of incorporation of the Corporation or change or convert in whole or in part the outstanding shares of the Corporation, any merger, consolidation, or share exchange of the Corporation or any subsidiary with:

            (A)           An interested shareholder; or

(B)           Another corporation, whether or not itself an interested shareholder, which is, or after the merger, consolidation, or share exchange would be, an affiliate of an interested shareholder that was an interested shareholder before the transaction.

(2)           A sale, lease, transfer, or other disposition, other than in the ordinary course of business, in one transaction or a series of transactions in any twelve-month period, to an interested shareholder or any affiliate of an interested shareholder, other than the Corporation or any of its subsidiaries, of any assets of the Corporation or any subsidiary having, measured at the time the transaction or transactions are approved by the board of directors of the Corporation, an aggregate book value as of the end of the Corporation’s most recently ended fiscal quarter of 10% or more of the total market value of the
 
 
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outstanding stock of the Corporation or of its net worth as of the end of its most recently ended fiscal quarter.

(3)           The issuance or transfer by the Corporation or any subsidiary, in one transaction or a series of transactions, of any equity securities of the Corporation or any subsidiary which has an aggregate market value of five percent or more of the total market value of the outstanding stock of the Corporation, to any interested shareholder or any affiliate of any interested shareholder, other than the Corporation or any of its subsidiaries, except pursuant to the exercise of warrants or rights to purchase securities offered pro rata to all holders of the Corporation’s voting stock or any other method affording substantially proportionate treatment of the holders of voting stock.

(4)           The adoption of a plan or proposal for the liquidation or dissolution of the Corporation in which anything other than cash will be received by an interested shareholder or an affiliate of an interested shareholder.

(5)           A reclassification of securities, including a reverse stock split or recapitalization of the Corporation, or any merger, consolidation, or share exchange of the Corporation with any of its subsidiaries which has the effect, directly or indirectly, in one transaction or a series of transactions, of increasing by five percent or more of the total number of outstanding shares the proportionate amount of the outstanding shares of any class or series of equity securities of the Corporation or any subsidiary which is directly or indirectly owned by an interested shareholder or an affiliate of an interested shareholder.

(e)           “Common stock” means stock other than preferred or preference stock.

(f)           “Control,” including the terms “controlling,” ”controlled by,” and “under common control with,” means the possession, directly or indirectly, of the power to direct or cause the direction of the management and policies of a person, whether through the ownership of voting securities, by contract, or otherwise.  The beneficial ownership of 10% or more of the votes entitled to be cast of a corporation’s voting stock creates a presumption of control.

(g)           “Equity security” means any of the following:

(1)           Stock or a similar security, certificate of interest, or participation on any profit sharing agreement, voting trust certificate, or certificate of deposit for an equity security.

(2)           A security convertible, with or without consideration, into an equity security, or any warrant or other security carrying any right to subscribe to or purchase an equity security.

(3)           Any put, call, straddle, or other option or privilege of buying an equity security from or selling an equity security to another without being bound to do so.

(h)           (l )           “Interested shareholder” means any person other than the Corporation or
 
 
 
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any subsidiary that is either of the following:

(A)           The beneficial owner, directly or indirectly, of 10% or more of the voting power of the outstanding voting stock of the Corporation.

(B)           An affiliate of the Corporation who at any time within the two-year period immediately before the date in question was the beneficial owner, directly or indirectly, of l0% or more of the voting power of the then outstanding voting stock of the Corporation.

(2)           For the purpose of determining whether a person is an interested shareholder, the number of shares of voting stock deemed to be outstanding shall include shares deemed owned by the person through application of subsection (c) of this section, but may not include any other shares of voting stock which may be issuable pursuant to any agreement, arrangement, or understanding, or upon exercise of conversion rights, warrants, or options, or otherwise.

(i)           “Market value” means the following:

(A)           In the case of stock, the highest closing sale price during the 30-day period immediately preceding the date in question of a share of such stock on the principal United States securities exchange registered under the Exchange Act on which such stock is listed, or if such stock is not listed on any such exchange, the highest closing bid quotation with respect to a share of such stock during the 30-day period preceding the date in question on the National Association of Securities Dealers, Inc., Automated Quotations System or any system then in use, or if no such quotations are available, the fair market value on the date in question of a share of such stock as determined by the board of directors of the Corporation in good faith.

(B)           In the case of property other than cash or stock, the fair market value of such property on the date in question as determined by the board of directors of the Corporation in good faith.

(j)           “Subsidiary” means any corporation of which voting stock having a majority of the votes entitled to be cast is owned, directly or indirectly, by the Corporation.

(k)           “Voting stock” means shares of capital stock of a corporation entitled to vote generally in the election of directors.

Section 2.             Vote Required in Business Combinations.  In addition to any vote otherwise required by law or the articles of incorporation of the Corporation, a business combination shall be recommended by the board of directors and approved by the affirmative vote of at least each of the following:

(a)           80% of the votes entitled to be cast by outstanding shares of voting stock of the Corporation voting together as a single voting group.
 
 
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(b)           Two-thirds of the votes entitled to be cast by holders of voting stock other than voting stock held by the interested shareholder who is or whose affiliate is a party to the business combination or an affiliate or associate of the interested shareholder, voting together as a single voting group.

Section 3.             When Voting Requirements Not Applicable.

(a)           Definitions. For purposes of subsection (b) of this section, the following terms shall have the indicated meanings:

(1)           “Announcement date” means the first general public announcement of a proposal or intention to make a proposal of a business combination or its first communication generally to shareholders of the Corporation, whichever is earlier.

(2)           “Determination date” means the date on which an interested shareholder first became an interested shareholder.

(3)           “Valuation date” means the following:

    (A)           For a business combination voted upon by shareholders, the later of (i) the day before the day of the shareholders” vote or (ii) the day 20 days before the consummation of the business combination.

 
(B)
For a business combination not voted upon by shareholders, the date of the consummation of the business combination.

(b)           Conditions. The vote required by section 2 of this article X shall not apply to a business combination, as defined in section 1 of this article X, if each of the following conditions is met:

(1 )           The aggregate amount of the cash and the market value as of the valuation date of consideration other than cash to be received per share by holders of common stock in such business combination is at least equal to the highest of the following:
 
             (A)     The highest per share price, including any brokerage commissions, transfer taxes, and soliciting dealers’ fees, paid by the interested shareholder for any shares of common stock of the same class or series that he acquired:
 
(i)           within the two-year period immediately before the announcement date of the proposal of the business combination; or

(ii)           in the transaction in which he became an interested shareholder, whichever is higher; or

    (B)           The market value per share of common stock of the same class or
 
 
 
31

 
 
 
series on the announcement date or on the determination date, whichever is higher; or

 
(C)
The price per share equal to the market value per share of common stock of the same class or series determined pursuant to subparagraph (B) immediately preceding, multiplied by the fraction of:

(i)           The highest per share price, including any brokerage commissions, transfer taxes, and soliciting dealers’ fees, paid by the interested shareholder for shares of common stock of the same class or series that he acquired within the two-year period immediately before the announcement date, over

(ii)           The market value per share of common stock of the same class or series on the first day in such two-year period on which the interested shareholder acquired shares of common stock.

(2)           The aggregate amount of the cash and the market value as of the valuation date of consideration other than cash to be received per share by holders of shares of any class or series of outstanding stock other than common stock is at least equal to the highest of the following, whether or not the interested shareholder has previously acquired shares of a particular class or series of stock:

    (A)           The highest per share price, including any brokerage commissions, transfer taxes, and soliciting dealers’ fees, paid by the interested shareholder for any shares of such class or series of stock that he acquired:

(i) within the two-year period immediately before the announcement date of the proposal of the business combination; or

(ii) in the transaction in which he became an interested shareholder, whichever is higher; or

    (B)           The highest preferential amount per share to which the holders of shares of such class or series of stock are entitled in the event of voluntary or involuntary liquidation, dissolution, or winding up of the Corporation; or

    (C)           The market value per share of such class or series of stock on the announcement date or on the determination date, whichever is higher; or
 
             (D)          The price per share equal to the market value per share of such class or series of stock determined pursuant to subparagraph (C) immediately preceding, multiplied by the fraction of:
 

(i)           The highest per share price, including any brokerage commissions, transfer taxes, and soliciting dealers’ fees, paid by the
 
 
 
 
32

 
 
 
interested shareholder for such shares of voting stock acquired by him within the two-year period immediately before the announcement date, over

(ii)           The market value per share of the same class or series of voting stock on the first day on such two-year period on which the interested shareholder acquired shares of the same class or series of voting stock.

(3)           The consideration to be received by holders of any class or series of outstanding stock is to be in cash or in the same form as the interested shareholder previously paid for shares of the same class or series of stock. If the interested shareholder has paid for shares of any class or series of stock with varying forms of consideration, the form of consideration for such class or series of stock shall be either cash or the form used to acquire the largest number of shares of such class or series of stock that he previously acquired.

(4)           (A)           After the interested shareholder has become an interested shareholder and before the consummation of such business combination:

(i)           There shall have been no failure to declare and pay at the regular date therefor any full periodic dividends, cumulative or not, on any outstanding preferred stock of the Corporation;

(ii)           There shall have been:

(aa)           No reduction in the annual rate of dividends paid on any class or series of stock of the Corporation that is not preferred stock except as necessary to reflect any subdivision of such stock; and

(bb)           An increase in such annual rate of dividends as shall have been necessary to reflect reclassification, including reverse stock split, recapitalization, reorganization, or similar transaction, which shall have the effect of reducing the number of outstanding shares of such stock; and
 
(iii)        The interested shareholder did not become the beneficial owner of additional shares of stock of the Corporation except as part of the transaction which resulted in such interested shareholder’s becoming an interested shareholder or by virtue of proportionate stock splits or stock dividends.
 

    (B)           The provisions of (i) and (ii) of subparagraph (A) shall not apply if neither an interested shareholder nor an affiliate or associate of an interested shareholder voted as a director of the Corporation in a manner inconsistent with (i) and (ii), and the interested shareholder, within 10 days after an act or failure to act inconsistent with such subparagraphs, shall have notified the board of directors of
 
 
33

 
 
 
 
the Corporation in writing that the interested shareholder disapproves thereof and requests in good faith that the board of directors rectify such act or failure to act.

(5)           After the interested shareholder has become an interested shareholder, the interested shareholder may not have received the benefit, directly or indirectly, except proportionately as a shareholder, of loans, advances, guarantees, pledges, or other financial assistance, or tax credits or other tax advantages, provided by the Corporation or any of its subsidiaries, whether in anticipation of or in connection with such business combination or otherwise.

(c)           Other Provisions.

(1)           Section 2 of this article X shall not apply to a business combination with a particular interested shareholder or his existing or future affiliates that has been approved or exempted therefrom by resolution of the board of directors of the Corporation; provided, however, that any such resolution shall have been adopted before the time that such interested shareholder first became an interested shareholder.

(2)           Unless by its terms a resolution adopted under this subsection is made irrevocable, it may be altered or repealed by the board of directors, but this shall not affect a business combination that has been consummated or is the subject of an existing agreement entered into before the alteration or repeal.

ARTICLE XI
 
Notices

Section 1.             Manner of Giving Notice. Notice required to be given under the provisions of these bylaws to a director, officer, or shareholder shall not be construed to mean personal notice, but may be given by depositing written or printed notice in a post office or letter box in a postpaid wrapper addressed to such director, officer, or shareholder at such address as appears on the books of the Corporation, such notice to be deemed to have been given at the time when the same shall have been thus mailed; or, if such person has provided a telecommunications address to the Corporation, such notice may be given by prepaid written telecommunication sent to such address and in such event shall be deemed to have been given at the time when the same shall have been transmitted.

Section 2.             Waiver of Notice. Any shareholder, officer, or director may waive, in writing or by written telecommunication, whether before or after the time stated, any notice required to be given under these bylaws.

 
34

 

ARTICLE XII
 
Miscellaneous

Section 1.             Fiscal Year. The fiscal year of the Corporation shall begin on the first day of January and end on the last day of December in each year.

Section 2.             Checks and Drafts. All checks, drafts, and orders for the payment of money shall be signed by the treasurer, in person or by facsimile or other authorized means, or by such other officer or officers or agents as the board of directors may from time to time designate. No check shall be signed in blank.

Section 3.             Books and Records. The books, accounts, and records of the Corporation shall, subject to the limitations fixed by law, be open to inspection by the shareholders at such times and subject to such regulations as the board of directors may prescribe.

Section 4.             Separability. If one or more of the provisions of these bylaws shall be held to be invalid, illegal, or unenforceable, such invalidity, illegality, or unenforceability shall not affect any other provision hereof and these bylaws shall be construed as if such invalid, illegal, or unenforceable provision or provisions had never been contained herein.


ARTICLE XIII
 
Amendment of Bylaws

Section 1.             Voting. These bylaws may be amended, repealed, or supplemented at any regular meeting of the board of directors, or at any special meeting called for such purpose, by the affirmative vote of a majority of the board of directors, or by unanimous written consent; provided, however, that in each instance an amendment, repeal, or supplement shall not be inconsistent with the law or the articles of incorporation of the Corporation and shall be subject to the power of the shareholders to amend, repeal, or supplement the bylaws so made but only upon the affirmative vote of at least 80% of all shares of capital stock entitled to vote thereon.

Section 2.             Shareholder Proposals. No proposal by a shareholder to amend, repeal, or supplement the bylaws of the Corporation may be voted upon at a meeting of shareholders unless, at least 180 days before such meeting of shareholders, such shareholder shall have delivered in writing to the secretary of the Corporation (a) notice of such proposal, including all information required by section 7(b)(3) of article II of these bylaws, (b) the text of the proposed amendment, repeal, or supplement and (c) an opinion of counsel, which counsel and the form and substance of which opinion shall be reasonably satisfactory to the board of directors of the Corporation, to the effect that the bylaws (if any) resulting from the adoption of such proposal would not be in conflict with the articles of incorporation of the Corporation or the laws of the State of Louisiana. In no event shall any adjournment, postponement or deferral of a meeting of shareholders or the announcement thereof commence a new time period for the giving of a shareholder’s notice as described above. Within 30 days after such shareholder shall have submitted the aforesaid items,
 
 
35

 
 
 
the secretary and the board of directors of the Corporation shall respectively determine whether the items to be ruled upon by them are reasonably satisfactory and shall notify such shareholder in writing of their respective determinations. If such shareholder fails to submit a required item in the form or within the time indicated, or if the secretary or the board of directors of the Corporation determine that the items to be ruled upon by them are not reasonably satisfactory, then such proposal by such shareholder may not be voted upon by the shareholders of the Corporation at such meeting of shareholders.

Section 3.             Effective Date. No amendment or supplement to or repeal of any of the following provisions of these bylaws, whether resulting from action of the directors or the shareholders, shall take effect until the later of (i) one year following the adoption of such amendment, supplement, or repeal, or (ii) 10 days after the adjournment sine die of the annual meeting of shareholders next succeeding the adoption of such amendment, supplement, or repeal:

Article II, section 2;
Article II, section 8;
Article X; and
Article XIII.

ARTICLE XIV
 
Other Amendments to Bylaws

Section 1.             Effective Date. No amendment or supplement to or repeal of any of the following provisions of these bylaws, whether resulting from action of the directors or the shareholders, shall take effect until the later of (i) one year following the adoption of such amendment, supplement, or repeal, or (ii) 10 days after the adjournment sine die of the annual meeting of shareholders next succeeding the adoption of such amendment, supplement, or repeal:

Article II, section 4;
Article II, section 5;
Article II, section 7;
Article II, section 9;
Article III, section 1;
Article III, section 2; and
Article XIV;

provided, however, that the board of directors shall have the power at any time, free from the foregoing restrictions, but subject to the provisions of subsection (g) of section 1 of article III of these bylaws, to amend or otherwise change subsections (a) and (d)(1) of section 1 of article III of these bylaws, and, with respect to any amendments to or changes in such subsection (d)(1), to make appropriate conforming changes in such section 1.

 
36

 

ARTICLE XV
 
Control Share Acquisition Statute

Section 1.             Pursuant to Section 136 of the Louisiana Business Corporation Law, the provisions of Sections 135 through 140.2 of the Louisiana Business Corporation Law, enacted as part of Title 12 of the Louisiana Revised Statutes, shall not apply to “control share acquisitions” (as defined therein) of this Corporation.
 
 
 
 
 
 
37


EX-12.A 3 exhibit12a.htm EXHIBIT 12(A) - COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES AND OF EARNINGS TO COMBINED FIXED CHARGES AND PREFERRED STOCK DIVIDENDS FOR THE THREE- AND TWELVE-MONTH PERIODS ENDED MARCH 31, 2011, FOR CLECO CORPORATION exhibit12a.htm


CLECO CORPORATION
EXHIBIT 12(a)
 

 
 
 
 
 
 
 
 
Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined
Fixed Charges and Preferred Stock Dividends
   
FOR THE THREE
MONTHS ENDED
   
FOR THE TWELVE
 MONTHS ENDED
 
(THOUSANDS, EXCEPT RATIOS)
 
MARCH 31, 2011
 
Earnings from continuing operations
  $ 29,016     $ 134,437  
Undistributed equity gain from investees
    (611 )     (1,613 )
Income taxes
    12,195       74,827  
Earnings from continuing operations before income taxes
  $ 40,600     $ 207,651  
Fixed charges:
               
Interest, long-term debt
  $ 21,916     $ 81,128  
Interest, other (including interest on short-term debt)
    4,628       17,423  
Amortization of debt expense, premium, net
    784       3,110  
Portion of rentals representative of an interest factor
    113       431  
Interest of capitalized lease
    462       1,903  
Total fixed charges
  $ 27,903     $ 103,995  
Earnings from continuing operations before income taxes
  $ 40,600     $ 207,651  
Plus:  total fixed charges from above
    27,903       103,995  
Plus:  amortization of capitalized interest
    128       512  
Earnings from continuing operations before income taxes and fixed charges
  $ 68,631     $ 312,158  
Ratio of earnings to fixed charges
    2.46  x     3.00  x
Total fixed charges from above
    27,903       103,995  
Preferred stock dividends
    16       72  
Total fixed charges and preferred stock dividends
    27,919       104,067  
Ratio of earnings to combined fixed charges and preferred stock dividends
    2.46  x     3.00  x




 
 
EX-12.B 4 exhibit12b.htm EXHIBIT 12(B) - COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES FOR THE THREE- AND TWELVE-MONTH PERIODS ENDED MARCH 31, 2011, FOR CLECO POWER exhibit12b.htm
 


CLECO POWER
EXHIBIT 12(b)
 
Computation of Ratios of Earnings to Fixed Charges
 
 
 
 
 
   
FOR THE THREE
MONTHS ENDED
   
FOR THE TWELVE
 MONTHS ENDED
 
(THOUSANDS, EXCEPT RATIOS)
 
MARCH 31, 2011
 
Earnings from continuing operations
  $ 30,030     $ 145,275  
Income taxes
    14,400       77,012  
Earnings from continuing operations before income taxes
  $ 44,430     $ 222,287  
Fixed charges:
               
Interest, long-term debt
  $ 20,844     $ 76,572  
Interest, other (including interest on short-term debt)
    3,674       7,214  
Amortization of debt expense, premium, net
    598       2,309  
Portion of rentals representative of an interest factor
    113       431  
Interest of capitalized lease
    462       1,903  
Total fixed charges
  $ 25,691     $ 88,429  
Earnings from continuing operations before income taxes
  $ 44,430     $ 222,287  
Plus:  total fixed charges from above
    25,691       88,429  
Earnings from continuing operations before income taxes and fixed charges
  $ 70,121     $ 310,716  
Ratio of earnings to fixed charges
    2.73  x     3.51  x
 


EX-31.1 5 exhibit311.htm EXHIBIT 31.1 - CEO CERTIFICATION IN ACCORDANCE WITH SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002 exhibit311.htm


 
CLECO CORPORATION
EXHIBIT 31.1
 
Certification

 
I, Michael H. Madison, certify that:

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

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

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

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

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

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

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

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

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

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

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

 

Date:  May 4, 2011
 
 
 
/s/ Michael H. Madison
Michael H. Madison
President and Chief Executive Officer


 


EX-31.2 6 exhibit312.htm EXHIBIT 31.2 - CFO CERTIFICATION IN ACCORDANCE WITH SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002 exhibit312.htm


 
CLECO CORPORATION
 EXHIBIT 31.2
 
Certification

I, Darren J. Olagues, certify that:

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

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

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

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

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

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

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

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

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

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

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



 
Date:  May 4, 2011
 
 
 
/s/  Darren J. Olagues
Darren J. Olagues
Senior Vice President & CFO 
 
 


EX-31.3 7 exhibit313.htm EXHIBIT 31.3 - CEO CERTIFICATION IN ACCORDANCE WITH SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002 exhibit313.htm


 
CLECO POWER LLC
 EXHIBIT 31.3
 
Certification

I, Michael H. Madison, certify that:

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

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

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

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

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

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

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

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

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

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

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


 

Date: May 4, 2011
 
 
 
/s/  Michael H. Madison
Michael H. Madison
Chief Executive Officer

 


EX-31.4 8 exhibit314.htm EXHIBIT 31.4 - CFO CERTIFICATION IN ACCORDANCE WITH SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002 exhibit314.htm


 
CLECO POWER LLC
EXHIBIT 31.4
 
Certification

I, Darren J. Olagues, certify that:

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

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

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

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

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

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

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

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

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

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

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


 
Date: May 4, 2011
 
 
 
/s/  Darren J. Olagues
Darren J. Olagues
Senior Vice President & CFO 

 


EX-32.1 9 exhibit321.htm EXHIBIT 32.1 - CEO CERTIFICATION PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002 exhibit321.htm


 
CLECO CORPORATION
EXHIBIT 32.1
 
 
 
Cleco Corporation
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
 
In connection with the Quarterly Report of Cleco Corporation (the “Company”) on Form 10-Q for the quarter ended March 31, 2011, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael H. Madison, President and Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
 
(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.


 

Date:  May 4, 2011
 
 
 
/s/  Michael H. Madison
Michael H. Madison
President and Chief Executive Officer
 


EX-32.2 10 exhibit322.htm EXHIBIT 32.2 - CFO CERTIFICATION PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002 exhibit322.htm


 
CLECO CORPORATION
EXHIBIT 32.2
 
 
 
Cleco Corporation
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
 
In connection with the Quarterly Report of Cleco Corporation (the “Company”) on Form 10-Q for the quarter ended March 31, 2011, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Darren J. Olagues, Senior Vice President & CFO of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
 
(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

 

Date:  May 4, 2011
 
 
 
/s/  Darren J. Olagues
Darren J. Olagues
Senior Vice President & CFO 
 
 


 
EX-32.3 11 exhibit323.htm EXHIBIT 32.3 - CEO CERTIFICATION PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002 exhibit323.htm


CLECO POWER LLC
EXHIBIT 32.3
 
 
 
Cleco Power LLC
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
 
In connection with the Quarterly Report of Cleco Power LLC (the “Company”) on Form 10-Q for the quarter ended March 31, 2011, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael H. Madison, Chief Executive Officer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
 
(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

 

Date:  May 4, 2011
 
 
 
/s/  Michael H. Madison
Michael H. Madison
Chief Executive Officer
 


 
EX-32.4 12 exhibit324.htm EXHIBIT 32.4 - CFO CERTIFICATION PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002 exhibit324.htm


 
CLECO POWER LLC
EXHIBIT 32.4
 
 
 
Cleco Power LLC
CERTIFICATION PURSUANT TO
18 U.S.C. SECTION 1350,
AS ADOPTED PURSUANT TO
SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002
 
In connection with the Quarterly Report of Cleco Power LLC (the “Company”) on Form 10-Q for the quarter ended March 31, 2011, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Darren J. Olagues, Senior Vice President & CFO of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

(1) The Report fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and
 
(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

 
Date:  May 4, 2011
 
 
 
/s/  Darren J. Olagues
Darren J. Olagues
Senior Vice President & CFO 

 


 
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