-----BEGIN PRIVACY-ENHANCED MESSAGE----- Proc-Type: 2001,MIC-CLEAR Originator-Name: webmaster@www.sec.gov Originator-Key-Asymmetric: MFgwCgYEVQgBAQICAf8DSgAwRwJAW2sNKK9AVtBzYZmr6aGjlWyK3XmZv3dTINen TWSM7vrzLADbmYQaionwg5sDW3P6oaM5D3tdezXMm7z1T+B+twIDAQAB MIC-Info: RSA-MD5,RSA, D+Lka4izSO9DTetS5Zexy+y9C0Y3skYkSYzdb7WK+Jf2SvC2syZPEnCkNrWAUdv2 LiZhlrxod7RQOM269OPGCw== 0001089819-07-000011.txt : 20070502 0001089819-07-000011.hdr.sgml : 20070502 20070502163550 ACCESSION NUMBER: 0001089819-07-000011 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 18 CONFORMED PERIOD OF REPORT: 20070331 FILED AS OF DATE: 20070502 DATE AS OF CHANGE: 20070502 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: 07811160 BUSINESS ADDRESS: STREET 1: 2020 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 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: 07811161 BUSINESS ADDRESS: STREET 1: 2030 DONAHUE FERRY ROAD CITY: PINEVILLE STATE: LA ZIP: 71360 BUSINESS PHONE: 3184847400 MAIL ADDRESS: STREET 1: 2030 DONAHUE FERRY ROAD CITY: PINEVILLE STATE: LA ZIP: 71360 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 10-Q 1 clecocorp10q_may207.htm CLECO CORPORATION AND CLECO POWER LLC SEC FORM 10-Q FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2007 Cleco Corporation and Cleco Power LLC SEC Form 10-Q for the Quarterly Period Ended March 31, 2007
 
 
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, 2007
 
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 Cleco Corporation is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):
Large accelerated filer   x                         Accelerated filer                                  Non-accelerated filer          
 
Indicate by check mark whether Cleco Power LLC is a large accelerated filer, an accelerated filer, or a non-accelerated filer. See definition of “accelerated filer and large accelerated filer” in Rule 12b-2 of the Exchange Act. (Check one):
Large accelerated filer                              Accelerated filer                                  Non-accelerated filer     x       
 
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 30, 2007
     
Cleco Corporation
Common Stock, $1.00 Par Value
59,684,966

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
2007 1ST QUARTER FORM 10-Q
 
This combined 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 Financial Statements are combined.
 
TABLE OF CONTENTS  
 
PAGE
GLOSSARY OF TERMS
3
DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS
5
     
PART I
Financial Information
  
ITEM 1.
Cleco Corporation — Condensed Consolidated Financial Statements
7
 
Cleco Power — Condensed Financial Statements
13
 
Notes to the Unaudited Condensed Financial Statements
17
ITEM 2.
Management’s Discussion and Analysis of Financial Condition and Results of Operations
33
ITEM 3.
Quantitative and Qualitative Disclosures about Market Risk
44
ITEM 4.
Controls and Procedures
46
   
 
PART II
Other Information
  
ITEM 1.
Legal Proceedings
47
ITEM 1A.
Risk Factors
47
ITEM 6.
Exhibits
48
 
Signatures
49


2
 
CLECO CORPORATION
CLECO POWER
2007 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, 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
Acadia
Acadia Power Partners, LLC and its 1,160-MW combined-cycle, natural gas-fired power plant near Eunice, Louisiana, 50% owned by APH and 50% owned by a subsidiary of Calpine
AFUDC
Allowance for Funds Used During Construction
Amended EPC Contract
Amended and Restated EPC Contract between Cleco Power and Shaw Constructors, Inc., executed on May 12, 2006, to engineer, design, and construct Rodemacher Unit 3.
APH
Acadia Power Holdings LLC, a wholly owned subsidiary of Midstream
Attala
Attala Transmission LLC, a wholly owned subsidiary of Cleco Corporation. Prior to February 1, 2007, Attala was a wholly owned subsidiary of Midstream.
Calpine
Calpine Corporation
Calpine Debtors
Calpine, CES, and certain other Calpine subsidiaries
Calpine Debtors Bankruptcy Court
U.S. Bankruptcy Court for the Southern District of New York
Calpine Tolling Agreements
Capacity Sale and Tolling Agreements between Acadia and CES which were suspended in March 2006
CCN
Certificate of Public Convenience and Necessity
CES
Calpine Energy Services, L.P.
Cleco Energy
Cleco Energy LLC, a wholly owned subsidiary of Midstream
Compliance Plan
The three-year plan included in the Consent Agreement in FERC Docket IN03-1-000
Consent Agreement
Stipulation and Consent Agreement, dated as of July 25, 2003, between Cleco and the FERC Staff
Diversified Lands
Diversified Lands LLC, a wholly owned subsidiary of Cleco Innovations LLC, a wholly owned subsidiary of Cleco Corporation
EITF
Emerging Issues Task Force of the FASB
EITF No. 03-6
Participating Securities and the Two-Class Method under FASB Statement No. 128, Earnings per Share
Entergy
Entergy Corporation
Entergy Gulf States
Entergy Gulf States, Inc.
Entergy Louisiana
Entergy Louisiana, Inc.
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
ERO
Electric Reliability Organization
ESOP
Cleco Corporation Employee Stock Ownership Plan
ESPP
Cleco Corporation Employee Stock Purchase Plan
Evangeline
Cleco Evangeline LLC, a wholly owned subsidiary of Midstream, and its 775-MW combined-cycle, natural gas-fired power plant located in Evangeline Parish, Louisiana
Evangeline Tolling Agreement
Capacity Sale and Tolling Agreement between Evangeline and Williams which expires in 2020
FASB
Financial Accounting Standards Board
FERC
Federal Energy Regulatory Commission
FIN
FASB Interpretation No.
FIN 45
Guarantor’s Accounting and Disclosure Requirements for Guarantees, Including Indirect Guarantees of Indebtedness to Others
FIN 46R
Consolidation of Variable Interest Entities - an Interpretation of Accounting Research Bulletin No. 51 (revised December 2003)
FIN 48
Accounting for Uncertainty in Income Taxes - an Interpretation of FASB Statement No. 109
ICT
Independent Coordinator of Transmission
Interconnection Agreement
Interconnection Agreement and Real Estate Agreement between Attala and Entergy Mississippi
IRP
Integrated Resource Planning
kWh
Kilowatt-hour(s) as applicable
LIBOR
London Inter-Bank Offer Rate
Lignite Mining Agreement
Dolet Hills Mine Lignite Mining Agreement, dated as of May 31, 2001
LPSC
Louisiana Public Service Commission
LTICP
Cleco Corporation Long-Term Incentive Compensation Plan
MAI
Mirant Americas, Inc., a wholly owned subsidiary of Mirant Corporation
Midstream
Cleco Midstream Resources LLC, a wholly owned subsidiary of Cleco Corporation
Moody’s
Moody’s Investors Service
MW
Megawatt(s) as applicable
 
3
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

ABBREVIATION OR ACRONYM
DEFINITION
Not meaningful
A percentage comparison of these items is not statistically meaningful because the percentage difference is greater than 1,000%
PEH
Perryville Energy Holdings LLC, a wholly owned subsidiary of Midstream
Perryville
Perryville Energy Partners, L.L.C., a wholly owned subsidiary of Cleco Corporation. Prior to February 1, 2007, Perryville was a wholly owned subsidiary of PEH.
Power Purchase Agreement
Power Purchase Agreement, dated as of January 28, 2004, between Perryville and Entergy Services
Registrant(s)
Cleco Corporation and Cleco Power
RFP
Request for Proposal
Rodemacher Unit 3
A 600-MW solid fuel generating unit under construction by Cleco Power at its existing Rodemacher plant site in Boyce, Louisiana
RSP
Rate Stabilization Plan
RTO
Regional Transmission Organization
Sale Agreement
Purchase and Sale Agreement, dated as of January 28, 2004, between Perryville and Entergy Louisiana
SEC
Securities and Exchange Commission
Senior Loan Agreement
Construction and Term Loan Agreement, dated as of June 7, 2001, between Perryville and KBC Bank N.V., as Agent Bank
SERP
Cleco Corporation Supplemental Executive Retirement Plan
SFAS
Statement of Financial Accounting Standards
SFAS No. 71
Accounting for the Effects of Certain Types of Regulation
SFAS No. 109
Accounting for Income Taxes
SFAS No. 123(R)
Share-Based Payment
SFAS No. 131
Disclosures about Segments of an Enterprise and Related Information
SFAS No. 133
Accounting for Derivative Instruments and Hedging Activities
SFAS No. 140
Accounting for Transfers and Servicing of Financial Assets and Extinguishments of Liabilities
SFAS No. 149
Amendment of Statement 133 on Derivative Instruments and Hedging Activities
SFAS No. 155
Accounting for Certain Hybrid Financial Instruments - an amendment of FASB Statements No. 133 and 140
SFAS No. 156
Accounting for Servicing of Financial Assets - an amendment of FASB Statement No. 140
SFAS No. 157
Fair Value Measurements
SFAS No. 159
The Fair Value Option For Financial Assets and Financial Liabilities - including an amendment to FAS 115
Shaw
Shaw Constructors, Inc., a subsidiary of The Shaw Group Inc.
Subordinated Loan Agreement
Subordinated Loan Agreement, dated as of August 23, 2002, between Perryville and MAI
Support Group
Cleco Support Group LLC, a wholly owned subsidiary of Cleco Corporation
SWEPCO
Southwestern Electric Power Company
VaR
Value-at-risk
Williams
Williams Power Company, Inc.

4
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
DISCLOSURE REGARDING FORWARD-LOOKING STATEMENTS 

This 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 Quarterly Report are forward-looking statements, including, without limitation, statements regarding the construction, timing and cost of Rodemacher Unit 3; Acadia settlement agreement between Cleco and Calpine; future capital expenditures; and future environmental regulations. 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, cost of and reliance on natural gas as a component of Cleco’s generation fuel mix and their impact on competition and franchises, fuel supply costs or availability constraints due to higher demand, shortages, transportation problems or other developments; environmental incidents; or 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 construct, operate, and maintain, within its projected costs (including financing) and timeframe, Rodemacher Unit 3, in addition to any other self-build projects identified in future IRP and RFP processes;
 
§  
Dependence of Cleco Power for energy from sources other than its facilities and the uncertainty of future long-term sources of such additional energy;
 
§  
Nonperformance by and creditworthiness of counterparties under tolling, power purchase, and energy service agreements, or the restructuring of those agreements, including possible termination;
 
§  
Outcome of the proposed settlement agreement, between Cleco and Calpine, associated with Calpine’s bankruptcy filing and its effect on Acadia;
 
§  
The final amount of storm restoration costs and storm reserve, if any, approved by the LPSC and the method through which such amounts can be recovered from Cleco Power’s customers;
 
§  
The final amount of recoverable lignite costs, as approved by the LPSC, that are currently deferred by Cleco Power;
 
§  
Regulatory factors such as changes in rate-setting policies, recovery of investments made under traditional regulation, the frequency and timing of rate increases or decreases, the results of periodic fuel audits, the results of IRP and RFP processes, the formation of RTOs and ICTs, and the establishment by an ERO of reliability standards for bulk power systems and compliance with these standards by Cleco Power, Acadia, Attala, Evangeline, and Perryville;
 
§  
Financial or regulatory accounting principles or policies imposed by the FASB, the SEC, the Public Company Accounting Oversight Board, the FERC, the LPSC or similar entities with regulatory or accounting oversight;
 
§  
Economic conditions, including the ability of customers to continue paying for high energy costs, related growth and/or down-sizing of businesses in Cleco’s service area, monetary fluctuations, changes in commodity prices, and inflation rates;
 
§  
Credit ratings of Cleco Corporation, Cleco Power, and Evangeline;
 
§  
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;
 
§  
Acts of terrorism;
 
§  
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;
 
§  
Employee work force factors, including work stoppages and changes in key executives;
 
§  
Legal, environmental, and regulatory delays and other obstacles associated with mergers, acquisitions, capital projects, reorganizations, or investments in joint ventures;
 
§  
Costs and other effects of legal and administrative proceedings, settlements, investigations, claims and other matters;
 
§  
Changes in federal, state, or local legislative requirements, tax laws or rates, regulating policies or environmental laws and regulations; and
 
§  
Ability of Cleco Power to recover, from its retail customers, the costs of compliance with environmental laws and regulations.
 
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, 2006.
 
5
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
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
2007 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, 2006. For more information on the basis of presentation, see “Notes to the Unaudited Condensed Financial Statements — Note 1 — Summary of Significant Accounting Policies — Basis of Presentation.”

7
 
CLECO CORPORATION
CLECO POWER
2007 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)
  
2007
 
2006
  
Operating revenue
          
Electric operations
  
$
213,020
  
$
210,989
  
Other operations
    
9,269
    
6,596
  
Affiliate revenue
    
1,461
    
1,451
  
Gross operating revenue
    
223,750
    
219,036
  
Electric customer credits
    
-
    
4,382
  
Operating revenue, net
    
223,750
    
223,418
  
Operating expenses
              
Fuel used for electric generation
    
55,496
    
48,363
  
Power purchased for utility customers
    
84,147
    
99,832
  
Other operations
    
26,315
    
18,088
  
Maintenance
    
10,241
    
5,933
  
Depreciation
    
20,098
    
15,645
  
Taxes other than income taxes
    
9,799
    
9,584
  
Total operating expenses
    
206,096
    
197,445
  
Operating income
   
17,654
    
25,973
  
Interest income
    
2,567
    
2,492
  
Allowance for other funds used during construction
    
5,131
    
669
  
Equity (loss) income from investees
    
(1,399
)
  
373
  
Other income
    
89
    
108
  
Other expense
    
(1,266
)
  
(328
)
Interest charges
              
Interest charges, including amortization of debt expenses, premium and discount, net of capitalized interest
    
13,657
    
11,176
  
Allowance for borrowed funds used during construction
    
(1,670
)
  
(227
)
Total interest charges
    
11,987
    
10,949
  
Income from continuing operations before income taxes
    
10,789
    
18,338
  
Federal and state income tax expense
   
2,143
    
6,113
  
Income from continuing operations
    
8,646
    
12,225
  
Discontinued operations
              
Loss from discontinued operations, net of tax
    
-
    
(87
)
Net income
   
8,646
    
12,138
  
Preferred dividends requirements, net of tax
    
423
    
459
  
Net income applicable to common stock
  
$
8,223
  
$
11,679
  
Average shares of common stock outstanding
              
Basic
    
57,854,737
    
49,851,812
  
Diluted
    
58,198,391
    
52,120,948
  
Basic earnings per share
              
From continuing operations
  
$
0.14
  
$
0.23
  
Net income applicable to common stock
  
$
0.14
  
$
0.23
  
Diluted earnings per share
              
From continuing operations
  
$
0.14
  
$
0.23
  
Net income applicable to common stock
  
$
0.14
  
$
0.23
  
Cash dividends paid per share of common stock
  
$
0.225
  
$
0.225
  
The accompanying notes are an integral part of the condensed consolidated financial statements.
              

8
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

CLECO CORPORATION
 
Condensed Consolidated Statements of Comprehensive Income (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
  
(THOUSANDS)
  
2007
  
2006
  
Net income
 
$
8,646
  
$
12,138
  
Other comprehensive income, net of tax:
              
Net unrealized (loss) gain from available-for-sale securities (net of tax (benefit) expense of $(18) in 2007 and $30 in 2006)
    
(28
)
  
48
  
Postretirement expense component (net of tax benefit of $3 in 2007)
    
(2
)
  
-
  
Other comprehensive (loss) income
   
(30
)
  
48
  
Comprehensive income, net of tax
 
$
8,616
  
$
12,186
  
The accompanying notes are an integral part of the condensed consolidated financial statements.
              

9
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

CLECO CORPORATION
 
Condensed Consolidated Balance Sheets (Unaudited)
(THOUSANDS)
  
At MARCH 31, 2007
  
AT DECEMBER 31, 2006
Assets
          
Current assets
          
Cash and cash equivalents
  
$
98,608
  
$
192,471
  
Restricted cash
    
11,247
    
24,361
  
Customer accounts receivable (less allowance for doubtful accounts of $855 in 2007 and $789 in 2006)
    
34,882
    
38,889
  
Accounts receivable - affiliate
    
14,044
    
11,451
  
Other accounts receivable
   
33,477
    
28,708
  
Unbilled revenue
    
16,006
    
18,382
  
Fuel inventory, at average cost
    
44,191
    
43,236
  
Material and supplies inventory, at average cost
    
40,178
    
34,755
  
Risk management assets
    
6,574
    
39
  
Accumulated deferred fuel
    
34,928
    
77,435
  
Cash surrender value of company-/trust-owned life insurance policies
    
26,618
    
26,275
  
Margin deposits
    
3,544
    
18,638
  
Prepayments
    
3,442
    
4,570
  
Regulatory assets - other
    
20,100
    
17,453
  
Other current assets
    
491
    
645
  
Total current assets
    
388,330
    
537,308
  
Property, plant and equipment
              
Property, plant and equipment
    
1,898,786
    
1,892,533
  
Accumulated depreciation
    
(892,197
)
  
(876,747
)
Net property, plant and equipment
    
1,006,589
    
1,015,786
  
Construction work in progress
    
381,482
    
289,101
  
Total property, plant and equipment, net
    
1,388,071
    
1,304,887
  
Equity investment in investees
    
315,033
    
307,136
  
Prepayments
    
6,540
    
6,515
  
Restricted cash
   
91
    
90
  
Regulatory assets and liabilities - deferred taxes, net
   
101,069
    
94,653
  
Regulatory assets - other
    
185,259
    
192,061
  
Other deferred charges
    
21,796
    
18,454
  
Total assets
  
$
2,406,189
  
$
2,461,104
  
The accompanying notes are an integral part of the condensed consolidated financial statements.
              

(Continued on next page)

10
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
CLECO CORPORATION
 
Condensed Consolidated Balance Sheets (Unaudited) (Continued)
(THOUSANDS)
  
At MARCH 31, 2007
  
AT DECEMBER 31, 2006
Liabilities and shareholders’ equity
          
Liabilities
          
Current liabilities
          
Long-term debt due within one year
  
$
40,000
  
$
50,000
  
Accounts payable
    
111,632
    
134,172
  
Retainage
    
18,066
    
12,409
  
Accounts payable - affiliate
    
19,364
    
5,072
  
Customer deposits
    
25,532
    
25,312
  
Provision for rate refund
    
6
    
3,174
  
Taxes accrued
    
23,354
    
49,002
  
Interest accrued
    
27,057
    
8,874
  
Accumulated current deferred taxes, net
    
20,036
    
23,233
  
Risk management liability
    
17,290
    
55,931
  
Regulatory liabilities - other
    
605
    
636
  
Deferred compensation
    
5,763
    
5,350
  
Other current liabilities
    
13,802
    
11,535
  
Total current liabilities
    
322,507
    
384,700
  
Deferred credits
              
Accumulated deferred federal and state income taxes, net
    
352,047
    
436,775
  
Accumulated deferred investment tax credits
    
13,742
    
14,100
  
Regulatory liabilities - other
    
10,221
    
5,827
  
Other deferred credits
    
194,562
    
104,140
  
Total deferred credits
    
570,572
    
560,842
  
Long-term debt, net
   
619,270
    
619,341
  
Total liabilities
    
1,512,349
    
1,564,883
  
Commitments and Contingencies (Note 8)
              
Shareholders’ equity
              
Preferred stock
              
Not subject to mandatory redemption, $100 par value, authorized 1,491,900 shares, issued 10,288 and 200,922 shares at
March 31, 2007 and December 31, 2006, respectively
    
1,029
    
20,092
  
Common shareholders’ equity
              
Common stock, $1 par value, authorized 100,000,000 shares, issued 59,598,835 and 57,605,695 shares and outstanding 59,453,159 and 57,524,498 shares at March 31, 2007 and December 31, 2006, respectively
    
59,453
    
57,524
  
Premium on common stock
    
378,235
    
358,707
  
Retained earnings
    
465,053
    
469,824
  
Treasury stock, at cost, 30,747 and 31,957 shares at March 31, 2007 and December 31, 2006, respectively
    
(590
)
  
(616
)
Accumulated other comprehensive loss
    
(9,340
)
  
(9,310
)
Total common shareholders’ equity
    
892,811
    
876,129
  
Total shareholders’ equity
    
893,840
    
896,221
  
Total liabilities and shareholders’ equity
  
$
2,406,189
  
$
2,461,104
  
The accompanying notes are an integral part of the condensed consolidated financial statements.
              


11
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
CLECO CORPORATION
 
Condensed Consolidated Statements of Cash Flows (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
  
(THOUSANDS)
  
2007
  
2006
  
Operating activities
          
Net income
 
$
8,646
  
$
12,138
  
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
              
Depreciation and amortization
    
21,001
    
16,506
  
Provision for doubtful accounts
    
501
    
646
  
Return on equity investment in investee
    
-
    
32
  
Loss (income) from equity investments
    
1,399
    
(373
)
Unearned compensation expense
    
3,028
    
831
  
ESOP expense
    
890
    
92
  
Allowance for other funds used during construction
    
(5,131
)
  
(669
)
Amortization of investment tax credits
    
(359
)
  
(383
)
Net deferred income taxes
   
1,939
    
3,931
  
Deferred fuel costs
   
(9,125
)
  
15,698
  
(Gain) loss on economic hedges
    
(1,459
)
  
1,876
  
Cash surrender value of company-/trust-owned life insurance
    
(343
)
  
(348
)
Changes in assets and liabilities:
              
Accounts receivable
    
(5,616
)
  
15,314
  
Accounts and notes receivable, affiliate
   
(2,256
)
  
47
  
Unbilled revenue
    
2,376
    
2,508
  
Fuel, materials and supplies inventory
    
(5,246
)
  
(24,984
)
Prepayments
    
1,103
    
450
  
Accounts payable
    
(21,045
)
  
(41,675
)
Accounts and notes payable, affiliate
    
697
    
4,165
  
Accrued payroll
    
(1,331
)
  
(1,366
)
Customer deposits
    
1,409
    
1,857
  
Regulatory assets and liabilities, net
    
3,951
    
(42,177
)
Other deferred accounts
    
(613
)
  
2,482
  
Retainage payable
    
5,657
    
303
  
Taxes accrued
    
(15,657
)
  
(267
)
Interest accrued
    
5,342
    
1,643
  
Margin deposits
    
15,094
    
(16,918
)
Other, net
    
2,655
    
120
  
Net cash provided by (used in) operating activities
    
7,507
    
(48,521
)
Investing activities
              
Additions to property, plant and equipment
    
(96,711
)
  
(20,213
)
Allowance for other funds used during construction
    
5,131
    
669
  
Return of equity investment in investee
    
95
    
2,771
  
Proceeds from sale of property, plant and equipment
    
-
    
229
  
Equity investment in investee
    
(20
)
  
(7,026
)
Transfer of cash from restricted accounts
    
13,113
    
-
  
Net cash used in investing activities
    
(78,392
)
  
(23,570
)
Financing activities
              
Conversion of options to common stock
    
382
    
571
  
Issuance of common stock under employee stock purchase plan
    
424
    
422
  
Stock based compensation tax benefit
    
43
    
68
  
Stock issuance costs
    
(4
)
  
-
  
Retirement of long-term obligations
    
(10,111
)
  
(66
)
Deferred financing costs
    
(341
)
  
(112
)
Change in ESOP trust
   
-
    
1,661
  
Dividends paid on preferred stock
    
(423
)
  
(910
)
Dividends paid on common stock
   
(12,948
)
  
(11,267
)
Net cash used in financing activities
    
(22,978
)
  
(9,633
)
Net decrease in cash and cash equivalents
    
(93,863
)
  
(81,724
)
Cash and cash equivalents at beginning of period
    
192,471
    
219,153
  
Cash and cash equivalents at end of period
  
$
98,608
  
$
137,429
  
Supplementary cash flow information
              
Interest paid (net of amount capitalized)
  
$
7,716
  
$
8,996
  
Income taxes paid 
  
$
15,000
  
$
23
  
Supplementary non-cash investing and financing activities
              
Issuance of treasury stock - LTICP and ESOP plans
  
$
25
  
$
27
  
Issuance of common stock - LTICP/ESOP/ESPP 1
  
$
20,030
  
$
1,538
  
Accrued additions to property, plant and equipment not reported above
  
$
50,092
  
$
20,453
  
1  Includes conversion of preferred stock to common stock ($19,063/2007, $799/2006)
              
The accompanying notes are an integral part of the condensed consolidated financial statements.
              

12
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

PART I— FINANCIAL INFORMATION
 
ITEM 1. CONDENSED FINANCIAL STATEMENTS
 
Cleco Power
These unaudited condensed financial statements should be read in conjunction with Cleco Power’s Financial Statements and Notes included in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2006. For more information on the basis of presentation, see “Notes to the Unaudited Condensed Financial Statements — Note 1 — Summary of Significant Accounting Policies — Basis of Presentation.”

13
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

CLECO POWER
 
Condensed Statements of Income (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
  
(THOUSANDS)
  
2007
  
2006
  
Operating revenue
          
Electric operations
  
$
213,020
  
$
210,989
  
Other operations
    
9,260
    
6,549
  
Affiliate revenue
    
513
    
512
  
Gross operating revenue
    
222,793
    
218,050
  
Electric customer credits
    
-
    
4,382
  
Operating revenue, net
    
222,793
    
222,432
  
Operating expenses
              
Fuel used for electric generation
    
55,496
    
48,363
  
Power purchased for utility customers
    
84,147
    
99,832
  
Other operations
    
25,613
    
17,622
  
Maintenance
    
9,727
    
5,347
  
Depreciation
    
19,761
    
15,225
  
Taxes other than income taxes
    
8,902
    
8,881
  
Total operating expenses
    
203,646
    
195,270
  
Operating income
    
19,147
    
27,162
  
Interest income
    
1,406
    
2,336
  
Allowance for other funds used during construction
    
5,131
    
669
  
Other income
    
94
    
67
  
Other expense
    
(342
)
  
(325
)
Interest charges
              
Interest charges, including amortization of debt expenses, premium and discount
    
11,714
    
9,206
  
Allowance for borrowed funds used during construction
    
(1,670
)
  
(227
)
Total interest charges
    
10,044
    
8,979
  
Income before income taxes
   
15,392
    
20,930
  
Federal and state income taxes
    
3,116
    
7,057
  
Net income
  
$
12,276
  
$
13,873
  
The accompanying notes are an integral part of the condensed financial statements.
              


14
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

CLECO POWER
 
Condensed Balance Sheets (Unaudited)
(THOUSANDS)
  
AT MARCH 31, 2007
  
AT DECEMBER 31, 2006
Assets
          
Utility plant and equipment
          
Property, plant and equipment
  
$
1,884,125
  
$
1,877,850
  
Accumulated depreciation
    
(883,649
)
  
(868,516
)
Net property, plant and equipment
    
1,000,476
    
1,009,334
  
Construction work in progress
    
380,702
    
288,455
  
Total utility plant, net
    
1,381,178
    
1,297,789
  
Current assets
              
Cash and cash equivalents
    
4,891
    
101,878
  
Restricted cash
    
11,247
    
24,361
  
Customer accounts receivable (less allowance for doubtful accounts of $855 in 2007 and $789 in 2006)
    
34,882
    
38,889
  
Other accounts receivable
    
33,099
    
28,399
  
Accounts receivable - affiliate
    
5,006
    
2,860
  
Unbilled revenue
    
16,006
    
18,382
  
Fuel inventory, at average cost
    
44,191
    
43,236
  
Material and supplies inventory, at average cost
    
40,178
    
34,755
  
Margin deposits
    
3,544
    
18,638
  
Risk management assets
    
6,574
    
39
  
Prepayments
    
2,847
    
3,713
  
Regulatory assets - other
    
20,100
    
17,453
  
Accumulated deferred fuel
    
34,928
    
77,435
  
Cash surrender value of life insurance policies
    
5,377
    
5,265
  
Other current assets
    
233
    
439
  
Total current assets
    
263,103
    
415,742
  
Prepayments
    
6,540
    
6,515
  
Regulatory assets and liabilities - deferred taxes, net
    
101,069
    
94,653
  
Regulatory assets - other
    
185,259
    
192,061
  
Other deferred charges
    
20,585
    
17,092
  
Total assets
  
$
1,957,734
  
$
2,023,852
  
Liabilities and member’s equity
              
Member’s equity
  
$
658,589
  
$
646,404
  
Long-term debt, net
    
519,270
    
519,341
  
Total capitalization
    
1,177,859
    
1,165,745
  
Current liabilities
              
Long-term debt due within one year
    
40,000
    
50,000
  
Accounts payable
    
108,861
    
128,411
  
Accounts payable - affiliate
    
18,757
    
35,469
  
Retainage
    
18,066
    
12,409
  
Customer deposits
    
25,532
    
25,312
  
Provision for rate refund
    
6
    
3,174
  
Taxes accrued
    
12,962
    
19,889
  
Interest accrued
    
21,503
    
7,707
  
Accumulated deferred taxes, net
    
19,355
    
22,582
  
Risk management liability
    
17,290
    
55,931
  
Regulatory liabilities - other
    
605
    
636
  
Other current liabilities
    
8,995
    
7,965
  
Total current liabilities
    
291,932
    
369,485
  
Deferred credits
              
Accumulated deferred federal and state income taxes, net
    
322,576
    
388,570
  
Accumulated deferred investment tax credits
    
13,742
    
14,100
  
Regulatory liabilities - other
    
10,221
    
5,827
  
Other deferred credits
    
141,404
    
80,125
  
Total deferred credits
    
487,943
    
488,622
  
Total liabilities and member’s equity
  
$
1,957,734
  
$
2,023,852
  
The accompanying notes are an integral part of the condensed financial statements.
              


15
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

CLECO POWER
 
Statements of Cash Flows (Unaudited)
   
FOR THE THREE MONTHS ENDED MARCH 31,
  
(THOUSANDS)
  
2007
  
2006
  
Operating activities
          
Net income
  
$
12,276
  
$
13,873
  
Adjustments to reconcile net income to net cash used in operating activities:
              
Depreciation and amortization
    
20,521
    
15,949
  
Provision for doubtful accounts
    
501
    
646
  
Unearned compensation expense
    
1,381
    
473
  
Allowance for other funds used during construction
    
(5,131
)
  
(669
)
Amortization of investment tax credits
    
(359
)
  
(383
)
Net deferred income taxes
    
(11,819
)
  
1,346
  
Deferred fuel costs
   
(9,125
)
  
15,698
  
(Gain) loss on economic hedges
    
(1,459
)
  
1,876
  
Cash surrender value of company-owned life insurance
    
(112
)
  
(108
)
Changes in assets and liabilities:
              
Accounts receivable
    
(5,547
)
  
13,654
  
Accounts and notes receivable, affiliate
    
(2,079
)
  
1,074
  
Unbilled revenue
    
2,376
    
2,508
  
Fuel, materials and supplies inventory
    
(5,246
)
  
(24,984
)
Prepayments
    
841
    
149
  
Accounts payable
    
(18,128
)
  
(36,695
)
Accounts and notes payable, affiliate
    
(16,941
)
  
6,286
  
Accrued payroll
    
(956
)
  
(973
)
Customer deposits
    
1,409
    
1,857
  
Regulatory assets and liabilities, net
    
3,951
    
(42,177
)
Other deferred accounts
    
(313
)
  
2,075
  
Retainage payable
    
5,657
    
303
  
Taxes accrued
    
658
    
(1,842
)
Interest accrued
    
3,588
    
(107
)
Margin deposits
    
15,094
    
(16,918
)
Other, net
    
760
    
(898
)
Net cash used in operating activities
    
(8,202
)
  
(47,987
)
Investing activities
              
Additions to property, plant and equipment
    
(96,578
)
  
(20,089
)
Allowance for other funds used during construction
    
5,131
    
669
  
Proceeds from sale of property, plant and equipment
    
-
    
229
  
Transfer of cash from restricted accounts
    
13,114
    
-
  
Net cash used in investing activities
    
(78,333
)
  
(19,191
)
Financing activities
              
Retirement of long-term obligations
    
(10,111
)
  
(66
)
Deferred financing costs
    
(341
)
  
(112
)
Net cash used in financing activities
    
(10,452
)
  
(178
)
Net decrease in cash and cash equivalents
    
(96,987
)
  
(67,356
)
Cash and cash equivalents at beginning of period
    
101,878
    
183,381
  
Cash and cash equivalents at end of period
  
$
4,891
  
$
116,025
  
Supplementary cash flow information
              
Interest paid (net of amount capitalized)
  
$
7,716
  
$
8,961
  
Supplementary non-cash investing and financing activities
              
Accrued additions to property, plant and equipment not reported above
  
$
50,092
  
$
20,453
  
The accompanying notes are an integral part of the condensed financial statements.
              

16
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
Index to Applicable Notes to the Unaudited Condensed Financial Statements of Registrants
 
Note 1
Summary of Significant Accounting Policies
Cleco Corporation and Cleco Power
Note 2
Regulatory Assets and Liabilities
Cleco Corporation and Cleco Power
Note 3
Disclosures about Segments
Cleco Corporation
Note 4
Equity Investment in Investees
Cleco Corporation
Note 5
Recent Accounting Standards
Cleco Corporation and Cleco Power
Note 6
Restricted Cash
Cleco Corporation and Cleco Power
Note 7
Electric Customer Credits
Cleco Corporation and Cleco Power
Note 8
Litigation and Other Commitments and Contingencies
Cleco Corporation and Cleco Power
Note 9
Disclosures about Guarantees
Cleco Corporation and Cleco Power
Note 10
Preferred Stock
Cleco Corporation
Note 11
Pension Plan and Employee Benefits
Cleco Corporation and Cleco Power
Note 12
Income Taxes
Cleco Corporation and Cleco Power
Note 13
Deferred Fuel and Purchased Power Costs
Cleco Corporation and Cleco Power
Note 14
Affiliate Transactions
Cleco Corporation and Cleco Power
Note 15
Calpine Bankruptcy
Cleco Corporation
Note 16
Subsequent Event
Cleco Corporation


17
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

Notes to the Unaudited Condensed Financial Statements
 
Note 1 — Summary of Significant Accounting Policies

Principles of Consolidation
The accompanying consolidated condensed financial statements of Cleco include the accounts of Cleco and its majority-owned subsidiaries after elimination of intercompany accounts and transactions.
Cleco has adopted the provisions of FIN 46R on its scheduled effective dates. Through a review of equity interests and other contractual relationships, Cleco has determined that it is not the primary beneficiary of one of its indirect, wholly owned subsidiaries and two of its wholly owned subsidiaries. Evangeline, Perryville, and Attala are considered variable interest entities. In accordance with FIN 46R, Cleco reports its investment in these entities 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’s equity investment in these entities. The pre-tax results of operations are reported as equity income from investees on Cleco Corporation’s Condensed Consolidated Statements of Income. For additional information on the operations of these entities, see Note 4 — “Equity Investment in Investees.”
 
Basis of Presentation
The condensed consolidated financial statements of Cleco Corporation and the condensed financial statements of 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 generally accepted accounting principles have been condensed or omitted, although 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 generally accepted accounting principles. The unaudited financial information included in the condensed financial statements of Cleco Corporation and Cleco Power reflects all adjustments of a normal recurring nature which are, in the opinion of the management of Cleco Corporation and Cleco Power, necessary for a fair statement of the financial position and the results of operations for the interim periods. Information for interim periods is affected by seasonal variations in sales, rate changes, timing of fuel expense recovery and other factors, and is not indicative necessarily of the results that may be expected for the full fiscal year. For more information on recent accounting standards and their effect on financial results, see Note 5 — “Recent Accounting Standards.”
 
Reclassifications
Certain reclassifications have been made to prior period financial statements to conform them to the presentation used in the current year’s financial statements. These reclassifications had no effect on Cleco Corporation’s net income applicable to common stock or total common shareholders’ equity or Cleco Power’s net income or total member’s equity.
 
Risk Management 
Market risk inherent in Cleco’s market risk-sensitive instruments and positions includes the potential change arising from changes in interest rates and the commodity market prices of power and natural gas on different energy exchanges. Cleco’s Trading Risk Management Policy authorizes the use of various derivative instruments, including 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 Power’s market risk-sensitive instruments and positions qualify for the normal-purchase, normal-sale exception to mark-to-market accounting of SFAS No. 133, as modified by SFAS No. 149, since Cleco Power generally takes physical delivery and the instruments and positions are used to satisfy customer requirements.
Cleco Power has entered into certain financial transactions it considers economic hedges to mitigate the risk associated with the fixed-price power to be provided to a wholesale customer through December 2010. The economic hedges cover approximately 97% of the estimated daily peak hour power sales to the wholesale customer. These transactions are derivatives as defined by SFAS No. 133 but do not meet the accounting criteria to be considered hedges. These transactions are marked-to-market with the resulting gain or loss recorded on the income statement as a component of operating revenue, net. For the three months ended March 31, 2007, there was a net mark-to-market gain of $1.5 million and a realized loss of less than $0.1 million recorded in other operations revenue related to these economic hedge transactions.
Cleco Power has entered into other positions to mitigate some of the volatility in fuel costs passed on to customers. 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 risk management assets or liabilities. When these positions close, actual gains or losses will be included in the fuel adjustment clause and reflected on customers’ bills as a component of the fuel cost adjustment. Based on market prices at March 31, 2007, the net mark-to-market impact relating to these positions was a loss of $13.2 million. Deferred losses relating to closed natural gas positions at March 31, 2007, totaled $3.5 million.
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 fixed-price power sales and volatility in customer fuel costs noted above. At March 31, 2007, Cleco Power had deposited collateral of
 
18
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
$3.5 million to cover margin requirements relating to open natural gas futures, options and swap positions.
Cleco and Cleco Power maintain a master netting agreement policy and monitor credit risk exposure through review of counterparty credit quality, corporate-wide aggregate counterparty credit exposure and corporate-wide aggregate counterparty concentration levels. Cleco actively 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.
 
Earnings per Average Common Share
Earnings per share is calculated in accordance with EITF No. 03-6 utilizing the “two-class” method by dividing earnings allocated to holders of common stock by the weighted average number of shares of common stock outstanding during the period. The following table shows the calculation of basic and diluted earnings per share.
                   
               
FOR THE THREE MONTHS ENDED MARCH 31,
  
           
2007
          
2006
  
 
(THOUSANDS, EXCEPT SHARES AND PER SHARE AMOUNTS)
 
INCOME
  
 
SHARES
  
PER SHARE
AMOUNT
  
 
INCOME
  
 
SHARES
  
PER SHARE
AMOUNT
  
Income from continuing operations
  
$
8,646
              
$
12,225
              
Deduct: non-participating stock dividends (4.5% preferred stock)
    
12
                
12
              
Deduct: participating preferred stock dividends
    
411
                
449
              
Deduct: amount allocated to participating preferred
    
-
                
22
              
Basic earnings per share
                                      
Income from continuing operations
 
$
8,223
        
$
0.14
  
$
11,742
        
$
0.23
  
Loss from discontinued operations
    
-
          
-
    
(87
)
        
-
  
Total basic net income applicable to common stock
  
$
8,223
    
57,854,737
  
$
0.14
  
$
11,655
    
49,851,812
  
$
0.23
  
Effect of Dilutive Securities
                                      
Add: stock option grants
    
-
    
170,251
          
-
    
94,382
        
Add: restricted stock (LTICP)
    
6
    
173,403
          
8
    
197,800
        
Add: convertible ESOP preferred stock
    
-
    
-
          
471
    
1,976,954
        
Diluted earnings per share
                                      
Income from continuing operations plus assumed conversions
  
$
8,229
        
$
0.14
  
$
12,221
        
$
0.23
  
Loss from discontinued operations
    
-
          
-
    
(87
)
        
-
  
Total diluted net income applicable to common stock
  
$
8,229
    
58,198,391
  
$
0.14
  
$
12,134
    
52,120,948
  
$
0.23
  
 
There were no stock option grants excluded from the computation of diluted earnings per share for the three months ended March 31, 2007, due to the average market price being higher than the exercise prices of the stock option grants. The stock option grants excluded from the computation of diluted earnings per share for the three months ended March 31, 2006, are presented in the table below. The stock option grants excluded from the computation of diluted earnings per share had exercise prices higher than the average market price.
       
   
FOR THE THREE MONTHS ENDED MARCH 31, 2006
  
   
 
STRIKE PRICE
  
AVERAGE
MARKET PRICE
  
 
SHARES
  
Stock option grants excluded
  
 
$22.00 - $24.25
  
 
$21.90
    
350,336
  
 
Stock-Based Compensation
At March 31, 2007, Cleco had one share-based compensation plan: the LTICP. Options or restricted shares of stock, known as non-vested stock as defined by SFAS No. 123(R), 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 26, 2007, Cleco granted 71,863 shares of non-vested stock and 55,249 of common stock equivalent units 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)
  
2007
 
2006
 
2007
 
2006
  
Equity classification
                  
Non-vested stock
  
$
625
  
$
300
  
$
250
  
$
190
  
Stock options
   
23
    
22
    
4
    
6
  
Non-forfeitable dividends
    
6
    
8
    
4
    
5
  
Total
  
$
654
  
$
330
  
$
258
  
$
201
  
Liability classification
                          
Common stock equivalent units
  
$
209
  
$
113
  
$
80
  
$
45
  
Company funded participants income tax obligations
    
2,085
    
331
    
1,043
    
227
  
Total
  
$
2,294
  
$
444
  
$
1,123
  
$
272
  
Total pre-tax compensation expense
  
$
2,948
  
$
774
  
$
1,381
  
$
473
  
Tax benefit (excluding income tax gross-up)
  
$
332
  
$
171
  
$
130
  
$
95
  

19
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

Note 2 — Regulatory Assets and Liabilities
Cleco Power follows SFAS No. 71, 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, 2007, and December 31, 2006:
           
   
AT MARCH 31,
 
AT DECEMBER 31,
 
(THOUSANDS)
  
2007
  
2006
  
Regulatory assets and liabilities - deferred taxes, net
  
$
101,069
  
$
94,653
  
Deferred mining costs
  
$
21,222
  
$
20,096
  
Deferred storm restoration costs - Lili/Isidore
    
2,425
    
2,772
  
Deferred storm restoration costs - Katrina/Rita
    
134,940
    
138,935
  
Deferred interest costs
    
8,159
    
8,430
  
Deferred asset removal costs
    
574
    
562
  
Deferred postretirement plan costs
    
38,039
    
38,719
  
Regulatory assets - other
  
$
205,359
  
$
209,514
  
Deferred fuel transportation revenue
  
$
(1,399
)
$
(1,566
)
Deferred construction carrying costs
    
(9,427
)
  
(4,897
)
Regulatory liabilities - other
  
$
(10,826
)
$
(6,463
)
Deferred fuel and purchased power
    
34,928
    
77,435
  
Total regulatory assets and liabilities, net
  
$
330,530
  
$
375,139
  

The decrease of $44.6 million in total regulatory assets and liabilities, net from December 31, 2006, to March 31, 2007, was primarily due to a reduction in the amount of Cleco Power’s deferred fuel and purchased power costs. This reduction is the result of a $47.1 million increase in the market value of open natural gas hedge positions and $4.5 million of lower deferred losses on closed natural gas hedge positions, both due to increases in natural gas prices. The increase in the mark-to-market and the lower deferred losses were partially offset by the deferral of $9.1 million in additional fuel and purchased power costs. For additional information on deferred fuel and purchased power costs, see Note 13 — “Deferred Fuel and Purchased Power Costs.” For additional information on natural gas hedges, see Note 1 — “Summary of Significant Accounting Policies — Risk Management.”
 
Deferred Taxes
Cleco Power has recorded SFAS No. 109 net regulatory assets related to probable future taxes payable that will be recovered from customers through future rates. Amounts recorded as regulatory assets are partially offset by deferred tax liabilities resulting from the regulatory requirement to flow through the current tax benefits to customers of certain accelerated deductions that are recovered from customers as they are paid. The recovery periods for regulatory assets and liabilities are based on assets’ lives, which are typically 30 years or greater. The amounts deferred are attributable to differences between book and tax recovery periods.
 
Deferred Storm Restoration Costs
At March 31, 2007, Cleco Power had approximately $2.4 million and $134.9 million of unamortized storm restoration costs relating to damage caused by Tropical Storm Isidore and Hurricane Lili and damage caused by Hurricanes Katrina and Rita, respectively. According to an agreement with the LPSC, approximately $8.2 million of restoration costs related to Isidore and Lili were recorded as a regulatory asset ($7.0 million in 2002 and $1.2 million in 2003) and are being amortized to maintenance expense over the six-year period which began in January 2003. The restoration costs relating to Hurricanes Katrina and Rita were being amortized to depreciation expense based on the amounts collected monthly from customers through a surcharge, according to the terms of an interim rate increase approved by the LPSC, until a review of the restoration costs could be completed by the LPSC. In March 2007, after completing this review, Cleco Power and the LPSC Staff filed a settlement agreement allowing the recovery of essentially all of Cleco Power’s Hurricanes Katrina and Rita storm costs. The agreement also allows Cleco Power to securitize the storm costs and to recover the costs through a customer billing surcharge. Management expects the settlement agreement to be approved by the LPSC in the third quarter of 2007.
 
Note 3 — Disclosures about Segments
Cleco’s reportable segments are based on its method of internal reporting, which disaggregates business units by first-tier subsidiary. Reportable segments were determined by applying SFAS No. 131. Cleco’s reportable segments are Cleco Power and Midstream. The reconciling items in the following tables consist of the holding company, a shared services subsidiary, two transmission substations, and an investment subsidiary. Effective February 1, 2007, the ownership interests of Midstream’s transmission interconnection facilities were transferred to Cleco Corporation. In accordance with SFAS No. 131, the prior period has been adjusted to reflect this change in organizational structure.
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 2007 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.

20
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

SEGMENT INFORMATION FOR THE THREE MONTHS ENDED MARCH 31,
   
CLECO
 
    
RECONCILING
          
2007 (THOUSANDS)
  
POWER
 
MIDSTREAM
  
ITEMS
  
ELIMINATIONS
  
CONSOLIDATED
  
Revenue
                      
Electric operations
  
$
213,020
  
$
-
  
$
-
  
$
-
  
$
213,020
  
Other operations
    
9,260
    
7
    
7
    
(5
)
  
9,269
  
Affiliate revenue
    
12
    
986
    
463
    
-
    
1,461
  
Intercompany revenue
    
501
    
-
    
12,396
    
(12,897
)
  
-
  
Operating revenue
  
$
222,793
  
$
993
  
$
12,866
  
$
(12,902
)
$
223,750
  
Depreciation expense
  
$
19,761
  
$
75
  
$
262
  
$
-
  
$
20,098
  
Interest charges
  
$
10,044
  
$
5,042
  
$
1,913
  
$
(5,012
)
$
11,987
  
Interest income
  
$
1,406
  
$
-
  
$
6,173
  
$
(5,012
)
$
2,567
  
Equity (loss) income from investees
  
$
-
  
$
(1,827
)
$
428
  
$
-
  
$
(1,399
)
Federal and state income tax expense (benefit)
  
$
3,116
  
$
(2,953
)
$
1,980
  
$
-
  
$
2,143
  
Segment profit (loss) (1)
  
$
12,276
  
$
(4,714
)
$
1,084
  
$
-
  
$
8,646
  
Additions to long-lived assets
 
$
99,738
  
$
-
  
$
134
  
$
-
  
$
99,872
  
Equity investment in investees
 
$
-
  
$
296,355
  
$
18,678
  
$
-
  
$
315,033
  
Total segment assets
 
$
1,957,734
  
$
316,919
  
$
478,867
  
$
(347,331
)
$
2,406,189
  
(1) Reconciliation of segment profit to consolidated profit:
    
Segment profit
              
$
8,646
        
 
Unallocated items: 
                  
 
  
    Preferred dividends
    requirements 
        
(423
)
      
 
Net income applicable to common stock 
$
8,223
        

                       
   
CLECO
      
RECONCILING
          
2006 (THOUSANDS)
  
POWER
  
MIDSTREAM
  
ITEMS
  
ELIMINATIONS
  
CONSOLIDATED
  
Revenue
                      
Electric operations
  
$
210,989
  
$
-
  
$
-
  
$
-
  
$
210,989
  
Other operations
    
6,549
    
4
    
43
    
-
    
6,596
  
Electric customer credits
    
4,382
    
-
    
-
    
-
    
4,382
  
Affiliate revenue
    
12
    
1,050
    
389
    
-
    
1,451
  
Intercompany revenue
    
500
    
-
    
9,137
    
(9,637
)
  
-
  
Operating revenue, net
  
$
222,432
  
$
1,054
  
$
9,569
  
$
(9,637
)
$
223,418
  
Depreciation expense
  
$
15,225
  
$
78
  
$
342
  
$
-
  
$
15,645
  
Interest charges
  
$
8,979
  
$
4,231
  
$
1,948
  
$
(4,209
)
$
10,949
  
Interest income
  
$
2,336
  
$
-
  
$
4,365
  
$
(4,209
)
$
2,492
  
Equity (loss) income from investees
  
$
-
  
$
(28
)
$
401
  
$
-
  
$
373
  
Federal and state income tax expense (benefit)
  
$
7,057
  
$
(1,695
)
$
806
  
$
(55
)
$
6,113
  
Segment profit (loss) from continuing operations, net
  
$
13,873
  
$
(3,271
)
$
1,623
  
$
-
  
$
12,225
  
Loss from discontinued operations, net of tax
    
-
    
(87
)
  
-
    
-
    
(87
)
Segment profit (loss) (1) 
  
$
13,873
  
$
(3,358
)
$
1,623
  
$
-
  
$
12,138
  
Additions to long-lived assets
 
$
50,690
  
$
8
  
$
116
  
$
-
  
$
50,814
  
Equity investment in investees (2)
  
$
-
  
$
302,167
  
$
4,969
  
$
-
  
$
307,136
  
Total segment assets (2)
  
$
2,023,852
  
$
325,157
  
$
751,376
  
$
(639,281
)
$
2,461,104
  
(1) Reconciliation of segment profit to consolidated profit:
    
Segment profit
              
$
12,138
        
(2) Balances as of December 31, 2006
  
   Unallocated items:
                  
 
    Preferred dividends
        requirements, net of tax 
        
(459
)
      
 
Net income applicable to common stock 
$
11,679
        
 

Note 4 — Equity Investment in Investees
Equity investment in investees represents primarily Midstream’s $236.9 million investment in Acadia, owned 50% by APH and 50% by Calpine, and its $59.4 million investment in Evangeline, owned 100% by Midstream. Equity investment in investees also represents a $7.1 million investment in Attala and a $11.5 million equity investment in Perryville, both owned 100% by Cleco Corporation. The remaining $0.1 million relates to equity investments held by Cleco Innovations LLC, a wholly owned subsidiary of Cleco Corporation.
Effective February 1, 2007, the ownership interests of Attala and Perryville were transferred from Midstream to Cleco Corporation. Cleco reports its investment in Acadia, Attala, Evangeline, Perryville and the investments held by Cleco Innovations LLC using 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 Condensed Consolidated Balance Sheets. The revenue and expenses (excluding income taxes) of these entities are netted and reported as equity income from investees on Cleco Corporation’s Condensed Consolidated Statements of Income.

21
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

The table below presents the equity (loss) income from each investment accounted for using the equity method.
       
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
  
2007
  
2006
  
APH
  
$
(2,395
)
$
(65
)
Attala
    
219
    
185
  
Evangeline
    
568
    
38
  
Perryville
    
219
    
240
  
Other
    
(10
)
  
(25
)
Total equity (loss) income
  
$
(1,399
)
$
373
  
 
APH’s equity income for the three-month period ended March 31, 2006, includes a $2.8 million draw against the $15.0 million letter of credit issued by Calpine. The remaining $12.2 million was drawn in August 2006. The letter of credit, of which APH is the beneficiary, was posted by Calpine to support its obligations under the Calpine Tolling Agreements.
 
Acadia
Cleco’s current assessment of its maximum exposure to loss at March 31, 2007, consists of its equity investment of $236.9 million.
The table below presents the components of Midstream's equity investment in Acadia.
           
   
AT MARCH 31,
  
AT DECEMBER 31,
 
INCEPTION TO DATE (THOUSANDS)
  
2007
  
2006
  
Contributed assets (cash and land)
  
$
250,612
  
$
250,612
  
Net income
   
103,303
    
105,698
  
Capitalized interest and other
   
19,469
    
19,469
  
Less: Cash distributions
    
136,464
    
136,464
  
Total equity investment in investee
  
$
236,920
  
$
239,315
  
 
Midstream’s equity, as reported on the balance sheet of Acadia at March 31, 2007, was $267.3 million.  The difference of $30.4 million between the equity investment in investee of $236.9 million as shown in the table above and Midstream’s equity includes $19.5 million of interest capitalized on funds contributed to Acadia.  It also includes other miscellaneous charges related to the construction of the Acadia facility offset by $57.4 million which represents the difference between the accounting treatments used by the partnership entities to record the allocation of termination agreement income.  The remaining $7.5 million is due to the difference in accounting treatment of the letter of credit draws between Acadia and APH. The cash distributions of $136.5 million were used to pay interest and repay principal on debt at Cleco Corporation relating to this investment. 
In December 2005, the Calpine Debtors, including CES and the subsidiary which owns the other 50% of Acadia, filed voluntary petitions in the Calpine Debtors Bankruptcy Court for protection under Chapter 11 of the U.S. Bankruptcy Code. In February 2006, APH drew $2.8 million against the $15.0 million Calpine letter of credit due to the default of CES under the tolling agreements. In August 2006, APH drew the remaining $12.2 million available under Calpine’s $15.0 million letter of credit. These amounts were reported as equity income from investees on Cleco Corporation’s Condensed Consolidated Statements of Income in the respective periods.
On April 23, 2007, Cleco announced that a settlement had been reached with Calpine that resolves issues surrounding the Calpine bankruptcy filing and its effect on the Acadia facility. For additional information, see Note 16 — “Subsequent Event.”
The table below contains summarized financial information for Acadia.
           
   
AT MARCH 31,
  
AT DECEMBER 31,
 
(THOUSANDS)
  
2007
  
2006
  
Current assets
  
$
5,356
  
$
5,233
  
Property, plant and equipment, net
    
433,512
    
437,281
  
Total assets
  
$
438,868
  
$
442,514
  
Current liabilities
  
$
3,928
  
$
3,327
  
Partners’ capital
    
434,940
    
439,187
  
Total liabilities and partners’ capital
  
$
438,868
  
$
442,514
  

       
   
FOR THE THREE MONTHS ENDED MARCH 31,
  
(THOUSANDS)
  
2007
  
2006
  
Total revenue
  
$
23,242
  
$
17,292
  
Total operating expenses
    
28,038
    
23,020
  
Other income
   
6
    
3
  
Loss before taxes
  
$
(4,790
)
$
(5,725
)
 
Income tax benefit recorded on APH’s financial statements related to Midstream’s 50% ownership interest in Acadia was $2.9 million and $1.7 million for the three months ended March 31, 2007, and 2006, respectively.
 
Attala
Cleco’s current assessment of its maximum exposure to loss at March 31, 2007, consists of its equity investment of $7.1 million. The table below presents the components of Cleco Corporation’s equity investment in Attala.
           
   
AT MARCH 31,
  
AT DECEMBER 31,
 
INCEPTION TO DATE (THOUSANDS)
  
2007
  
2006
  
Contributed assets (cash)
  
$
7,006
  
$
7,006
  
Income before taxes
    
1,121
    
902
  
Less: distributions
   
1,011
    
972
  
Total equity investment in investee
  
$
7,116
  
$
6,936
  
 
The table below contains summarized financial information for Attala.
           
   
AT MARCH 31,
 
AT DECEMBER 31,
 
(THOUSANDS)
  
2007
  
2006
  
Current assets
  
$
240
  
$
249
  
Other assets
    
6,933
    
6,930
  
Total assets
  
$
7,173
  
$
7,179
  
Current liabilities
  
$
45
  
$
63
  
Accounts payable - affiliate
    
12
    
180
  
Other liabilities
    
45
    
-
  
Member’s equity
    
7,071
    
6,936
  
Total liabilities and member’s equity
  
$
7,173
  
$
7,179
  

       
   
FOR THE THREE MONTHS ENDED MARCH 31,
  
(THOUSANDS)
  
2007
  
2006
  
Operating revenue
  
$
260
  
$
207
  
Operating expenses
    
41
    
22
  
Income before taxes
  
$
219
  
$
185
  
 
22
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
The $6.9 million in Other assets in the summarized financial information for Attala listed above primarily consists of the transmission assets utilized by Attala in the Interconnection Agreement. These transmission assets are accounted for as a direct financing lease on Attala’s Balance Sheet at March 31, 2007.
Income tax expense recorded on Cleco’s financial statements related to Cleco Corporation’s 100% interest in Attala was $0.1 million for the three months ended March 31, 2007, and 2006.
 
Evangeline
Cleco’s current assessment of its maximum exposure to loss at March 31, 2007, consists of its equity investment of $59.4 million.
The table below presents the components of Midstream's equity investment in Evangeline.
           
   
AT MARCH 31,
  
AT DECEMBER 31,
 
INCEPTION TO DATE (THOUSANDS)
  
2007
  
2006
  
Contributed assets (cash)
  
$
43,580
  
$
43,580
  
Net income
   
136,750
    
136,182
  
Less: distributions
   
120,895
    
116,910
  
Total equity investment in investee
  
$
59,435
  
$
62,852
  
 
The table below contains summarized financial information for Evangeline. 
   
 
      
   
AT MARCH 31,
 
AT DECEMBER 31,
  
(THOUSANDS)
  
2007
  
2006
  
Current assets
  
$
9,639
  
$
17,162
  
Accounts receivable - affiliate
    
5,948
    
5,052
  
Property, plant and equipment, net
    
184,933
    
185,958
  
Other assets
    
48,367
    
48,429
  
Total assets
  
$
248,887
  
$
256,601
  
Current liabilities
  
$
15,695
  
$
17,453
  
Accounts payable - affiliate
    
812
    
4,611
  
Long-term debt
    
172,965
    
177,064
  
Other liabilities
    
62,823
    
61,233
  
Member’s deficit
    
(3,408
)
  
(3,760
)
Total liabilities and member’s deficit
  
$
248,887
  
$
256,601
  

       
   
FOR THE THREE MONTHS ENDED MARCH 31,
  
(THOUSANDS)
  
2007
  
2006
  
Operating revenue
  
$
10,545
  
$
10,343
  
Operating expenses
    
4,524
    
4,894
  
Depreciation
    
1,286
    
1,308
  
Interest charges
    
4,522
    
4,265
  
Interest income
    
358
    
294
  
Other expense
    
3
    
132
  
Income before taxes
  
$
568
  
$
38
  
 
Since its inception, Cleco has had 100% ownership and voting interest of Evangeline. All of the capacity and output of the power plant has been tolled to Williams, which pays Evangeline certain fixed and variable amounts.
At March 31, 2007, Evangeline had a member’s deficit of $3.4 million. This deficit was caused by Evangeline’s ability to generate cash, either through operations or through income tax savings, that was distributed to its member in excess of its net income. The deficit did not cause a default under Evangeline’s 8.82% Senior Secured Bonds due 2019 and is not expected to impact Evangeline’s ability to fund its operations.
Income tax expense recorded on Midstream’s financial statements related to Midstream’s 100% ownership interest in Evangeline was $0.2 million for the three months ended March 31, 2007, and 2006.
 
Perryville
Cleco’s current assessment of its maximum exposure to loss at March 31, 2007, consists of its equity investment of $11.5 million.
The table below presents the components of Cleco Corporation’s equity investment in Perryville.
           
   
AT MARCH 31,
  
AT DECEMBER 31,
 
INCEPTION TO DATE (THOUSANDS)
  
2007
  
2006
  
Contributed assets (cash)
  
$
102,174
  
$
102,174
  
Net income
   
50,505
    
50,285
  
Less: distributions
   
141,137
    
154,532
  
Total equity (return of) investment in investee
  
$
11,542
  
$
(2,073
)
 
The table below contains summarized financial information for Perryville.
           
   
AT MARCH 31,
  
AT DECEMBER 31,
  
(THOUSANDS)
  
2007
  
2006
  
Current assets
  
$
289
  
$
42
  
Accounts receivable - affiliate
    
13,416
    
107
  
Other assets
    
10,221
    
9,385
  
Total assets
  
$
23,926
  
$
9,534
  
Current liabilities
  
$
4,640
  
$
16
  
Accounts payable - affiliate
    
9,645
    
11
  
Other liabilities
    
328
    
329
  
Member’s equity
    
9,313
    
9,178
  
Total liabilities and member’s equity
  
$
23,926
  
$
9,534
  
 
The transmission assets utilized by Perryville in an interconnection agreement with Entergy Louisiana are accounted for as a direct financing lease by Perryville, and are included in Other assets in the summarized financial information above.
       
   
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
  
2007
  
2006
  
Operating revenue
  
$
263
  
$
264
  
Operating expenses
    
44
    
163
  
Interest income
    
-
    
139
  
Income before taxes
  
$
219
  
$
240
  
 
Income tax expense recorded on Cleco’s financial statements related to Cleco Corporation’s 100% interest in Perryville was $0.1 million for the three months ended March 31, 2007, and 2006.
 
Note 5 — Recent Accounting Standards
The Registrants adopted, or will adopt, the recent accounting standards listed below on their respective effective dates.
In February 2006, the FASB issued SFAS No. 155 which amends SFAS No. 133 and SFAS No. 140. The provisions of this statement:
 
23
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
§  
permit fair value accounting for hybrid financial instruments that contain an embedded derivative that otherwise would require bifurcation;
§  
clarify the exemption from SFAS No. 133 for certain interest-only and principal-only strips;
§  
establish a requirement to evaluate interests in securitized financial assets that contain an embedded derivative requiring bifurcation;
§  
clarify that concentrations of credit risk in the form of subordination are not embedded derivatives; and
§  
amend SFAS No. 140 as it relates to qualifying special-purpose entities and derivative financial instruments.
 
This statement is effective for all financial instruments acquired, issued or subject to a remeasurement event occurring after the beginning of an entity’s first fiscal year that begins after September 15, 2006. The adoption of SFAS No. 155 did not have an impact on the financial condition or results of operations of the Registrants.
In March 2006, the FASB issued SFAS No. 156 which amends SFAS No. 140 with respect to the accounting for separately recognized servicing assets and liabilities. This statement requires all separately recognized servicing assets and liabilities to be initially measured at fair value, requires fair value accounting for derivative instruments used to mitigate risks of the servicing assets and liabilities, and allows for the election to use fair value accounting for the servicing assets and liabilities in subsequent periods. SFAS No. 156 is effective for the first fiscal year beginning after September 15, 2006. The adoption of SFAS No. 156 did not have an impact on the financial condition or results of operations of the Registrants.
In July 2006, the FASB issued FIN 48, which provides guidance on accounting for uncertain tax positions. FIN 48 allows recognition of those tax benefits that satisfy a greater than 50% probability threshold. This interpretation requires each tax position to be evaluated using a two-step process. The first step is a determination of the likelihood the position will be sustained upon examination based upon the technical merits of the position. For tax positions that result from permanent differences between book and tax income, the company must evaluate the likelihood that the position will be sustained to determine whether a tax benefit can be recognized. Once it is determined that a tax benefit can be recognized, the second step is to measure and record the tax benefit to be realized. For tax positions that do not meet the requirements of the first step, no tax benefit should be recognized. This interpretation also provides for the recognition and measurement of expected penalties and interest, as well as disclosure requirements about tax positions. This interpretation is effective for fiscal years beginning after December 15, 2006. For additional information regarding the impact the adoption of FIN 48 had on the financial condition and results of operations of the Registrants, see Note 12 — “Income Taxes.”
In September 2006, the FASB issued SFAS No. 157, which provides guidance on how companies should measure fair value when required for recognition or disclosure purposes under generally accepted accounting principles. Specifically, SFAS No. 157 creates a common definition of fair value throughout generally accepted accounting principles, establishes a fair value hierarchy, and requires companies to make expanded disclosures about fair value measurements. This statement is effective for fiscal years beginning after November 15, 2007. Management is currently evaluating the impact this statement will have on the financial condition and results of operations of the Registrants.
In February 2007, the FASB issued SFAS No. 159, which allows entities to choose, at specified election dates, to measure eligible financial assets and liabilities at fair value that are not otherwise required to be measured at fair value. SFAS No. 159 is effective for fiscal years beginning after November 15, 2007. Management is currently evaluating the impact this statement will have on the financial condition and results of operations of the Registrants.
 
Note 6 — 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, 2007, and December 31, 2006, $0.1 million of cash was restricted under the Diversified Lands mitigation escrow agreement. Also, at March 31, 2007, and December 31, 2006, $11.2 million and $24.4 million of cash, respectively, was restricted under the Cleco Power solid waste disposal bonds indenture. Restricted cash at Cleco Power decreased $13.2 million compared to December 31, 2006, due to the release of funds for construction of the solid waste disposal facility at Rodemacher Unit 3.
 
Note 7 — Electric Customer Credits
Cleco’s and Cleco Power’s reported earnings for the three months ended March 31, 2006, reflect reversals of previously accrued credits of $4.4 million under terms of a RSP established in an earnings review settlement with the LPSC in 1996. Neither Cleco nor Cleco Power accrued or reversed any previously accrued credits for the three months ended March 31, 2007.
The original terms of the 1996 LPSC earnings review settlement were extended without modification to September 30, 2006, through subsequent amendments and two approved one-year extensions. As part of the settlement, Cleco Power was allowed to retain all regulated earnings up to a 12.25% return on equity, and to share equally with customers, as credits on their bills, all regulated earnings between 12.25% and 13% return on equity. All regulated earnings above a 13% return on equity were credited to customers. This effectively allowed Cleco Power the opportunity to realize a regulatory rate of return up to 12.625%. The amount of credits due customers, if any, is determined by Cleco Power and the LPSC annually, based on results for each 12-month period ended September 30. The 1996 LPSC settlement provided for such credits to be made on customers’ bills the following summer.
 
24
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
In July 2006, Cleco Power’s request for an extension of the RSP to the in-service date of Rodemacher Unit 3, targeted for the fourth quarter of 2009, was approved by the LPSC with several modifications to the terms of the original RSP. Effective October 1, 2006, Cleco Power began operating under the new RSP, which allows Cleco Power to earn a maximum regulated return on equity of 11.65%. This maximum return is based on a return on equity of 11.25%, with any regulated earnings between 11.25% and 12.25% shared between shareholders and customers in a 40/60 ratio. All regulated earnings over 12.25% will be returned to customers. The terms relating to the sharing of regulated earnings were modified by the LPSC in its order approving the recovery of storm restoration costs discussed below.
In April 2006, the LPSC approved a recommendation of the LPSC Staff requiring Cleco Power to refund $1.3 million to customers relating to Cleco Power’s RSP filings for the 12-month periods ended September 30, 2002, 2003, and 2004. Cleco Power refunded the amount as credits on customers’ September 2006 utility bills. Coincident with the $1.3 million refund, in the first quarter of 2006 Cleco Power reversed previously accrued customer credits of $3.2 million for the periods ended September 30, 2002, 2003, and 2004. In this same proceeding, the LPSC also reserved the right to further review Cleco Power’s calculation of working capital included in the filings for the 12-month periods ended September 30, 2002, 2003, and 2004. Cleco Power reached an agreement of the working capital issue with the LPSC and refunded an additional $3.2 million of previously accrued customer credits to customers in March 2007.
In April 2006, Cleco Power filed its required monitoring report for the 12-month period ended September 30, 2005. Based on the reassessment of amounts filed in this monitoring report, the results of the Staff’s review as discussed above, and projections for the year 2006, in the first quarter of 2006 Cleco Power reversed $1.2 million of customer credits previously accrued for the 12-month periods ended September 30, 2005, and 2006. The LPSC consultants completed the review of the 2005 monitoring report in March 2007. Cleco Power received the LPSC Staff’s report in April 2007, indicating that no refund is due based on the 2005 RSP filing.
Cleco Power filed its RSP monitoring report with the LPSC for the 12-month period ended September 30, 2006, on March 30, 2007. The LPSC consultants have begun their review of the 2006 filing. Cleco Power anticipates the review will be completed by the end of 2007.
Cleco Power’s Balance Sheets at March 31, 2007, and December 31, 2006, reflect the following accruals for estimated electric customer credits relating to the 12-month periods ended September 30, 2002, through September 30, 2007.
           
   
AT MARCH 31,
  
AT DECEMBER 31,
  
(THOUSANDS)
  
2007
  
2006
  
Provision for rate refund
  
$
6
  
$
3,174
  
Other deferred credits
    
1,933
    
1,933
  
Total customer credits
  
$
1,939
  
$
5,107
  
 
Amounts reported under the line item provision for rate refund relate to the 12-month period ended September 30, 2002, and reflect estimated amounts due currently. The amounts reported under the line item other deferred credits currently are not due. All customer credits relating to Cleco Power’s RSP were recorded as a reduction in revenue due to the nature of the credits. The accruals are based upon the original 1996 settlement, the modified terms of the RSP extension, the resolution of the 2001-2002 fuel audit which was settled in 2004, annual issues as agreed to between Cleco and the LPSC, and Cleco’s assessment of issues that remain outstanding.
In February 2006, the LPSC approved Cleco Power’s request to recover storm restoration costs incurred for Hurricanes Katrina and Rita. As part of this approval, the LPSC required that effective during the interim recovery period (Phase I), which began with the May 2006 billing cycle, Cleco Power’s portion of the shared regulated earnings between the 12.25% and 13.00% allowed return on equity (between 11.25% and 12.25% effective October 1, 2006) be credited against outstanding Hurricanes Katrina and Rita storm restoration costs, rather than being shared between shareholders and customers. In March 2007, as a result of Phase II of the LPSC Staff’s review of storm restoration costs, Cleco Power and the LPSC Staff filed a settlement agreement with the LPSC allowing the recovery of essentially all of Cleco Power’s Hurricanes Katrina and Rita storm costs. As part of the agreement, Cleco Power will continue to forgo its share of any excess earnings calculated according to the terms of the current RSP (unless modified in a subsequent base rate proceeding). For information concerning this agreement, see Note 2 — “Regulatory Assets and Liabilities.” As of March 31, 2007, Cleco Power had not credited any earnings against storm restoration costs.
 
Note 8 — Litigation and Other Commitments and Contingencies
 
Other Litigation
On June 22, 2005, the City of Alexandria, Louisiana (the City), a current wholesale municipal customer of Cleco Power, filed a lawsuit in Ninth Judicial District Court against Cleco Corporation, Cleco Power, and certain other subsidiaries. The lawsuit alleges unspecified damages as a result of certain sales made to the City, revenue derived by Cleco using the City’s power generating facilities under contracts with the City, and other alleged improper conduct, including, without limitation, allegations that Cleco fraudulently mishandled the management of the City’s power requirements under the contracts. The lawsuit was removed to and currently is pending in the U.S. District Court for the Western District of Louisiana. Cleco filed responses which include claims for unspecified amounts owed by the City to Cleco. On January 13, 2006, Cleco and the City agreed upon guidelines whereby an audit and subsequent mediation of the disputed transactions would be performed. On February 21, 2006, the court designated KPMG LLP (KPMG) to examine the claims made by both parties and subsequently serve as the mediator. On February 23, 2007,
 
25
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
KPMG delivered a preliminary audit report to outside counsel for each party. Pursuant to a court order, the report’s distribution is limited and its contents are confidential. In March 2007, the parties met to mediate the dispute and have agreed to continue to negotiate a framework for resolution of the dispute under the supervision of the mediator and U.S. District Judge. Management believes the dispute will not have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows.
Cleco is involved in regulatory, environmental, and legal proceedings before various courts, regulatory commissions, and governmental agencies regarding matters arising in the ordinary course of business. Some of these proceedings, such as fuel review and environmental issues, could involve substantial amounts. Management regularly analyzes current information and, as necessary, provides accruals for probable liabilities on the eventual disposition of these matters. Management believes the disposition of these matters will not have a material adverse effect on the Registrants’ financial condition, results of operations, or cash flows. In several lawsuits, Cleco has been named as a defendant by individuals who claim injury due to exposure to asbestos while working at sites in central Louisiana. Most of the claimants were workers who participated in the construction of various generation facilities, and some of the claimants had worked at locations owned by Cleco. With two exceptions, all filed, asbestos-related lawsuits have been settled. The result of the settlements had no material impact on Cleco’s financial condition, results of operations, or cash flows. The two remaining lawsuits were dismissed by the trial court; however, the claimants appealed the trial court’s dismissal. On March 21, 2007, the appeals court affirmed the trial court’s dismissal. On April 19, 2007, the claimants filed a request for review of the appeals court decision with the Louisiana Supreme Court. Management believes that the eventual disposition of these lawsuits will have no material impact on the Registrants’ financial condition, results of operations, or cash flows. There is no assurance that new asbestos-related lawsuits will not be filed against the Registrants in the future.
 
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 entered into these off-balance sheet commitments in order to entice desired counterparties to contract with its affiliates by providing some measure of credit assurance to the counterparty in the event Cleco’s affiliates do not fulfill certain contractual obligations. If Cleco Corporation had not provided the off-balance sheet commitments, the desired counterparties may not have contracted with Cleco’s affiliates or may have contracted with them at terms less favorable to its affiliates.
The off-balance sheet commitments are not recognized on Cleco’s Condensed Consolidated Balance Sheets, because it has been 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. Some of these commitments reduce borrowings available to Cleco Corporation under its credit facility pursuant to the terms of the credit facility. Cleco’s off-balance sheet commitments as of March 31, 2007, 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, 2007
  
             
REDUCTIONS TO THE
  
             
AMOUNT AVAILABLE
  
             
TO BE DRAWN ON
  
 
FACE
      
NET
 CLECO CORPORATION’S
  
(THOUSANDS)
AMOUNT
  
REDUCTIONS
  
AMOUNT
  
CREDIT FACILITY
  
Cleco Corporation
                
Guarantee issued to Entergy companies for performance obligations of Perryville
$
277,400
  
$
135,000
  
$
142,400
  
$
328
  
Guarantees issued to purchasers of the assets of Cleco Energy
 
1,400
    
-
    
1,400
    
1,400
  
Obligations under standby letter of credit issued to the Evangeline Tolling Agreement
    counterparty
  
15,000
    
-
    
15,000
    
15,000
  
Guarantee issued to Entergy Mississippi on behalf of Attala
  
500
    
-
    
500
    
500
  
Cleco Power
                        
Obligations under standby letter of credit issued to the Louisiana Department of Labor
  
525
    
-
    
525
    
-
  
Obligations under the Lignite Mining Agreement
  
10,920
    
-
    
10,920
    
-
  
Obligations under standby letter of credit issued to the Louisiana Department of Wildlife and
    Fisheries
  
85
    
-
    
85
    
-
  
Total
$
305,830
  
$
135,000
  
$
170,830
  
$
17,228
  
 
Cleco Corporation provided a limited guarantee 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. As of March 31, 2007, the aggregate guarantee of $277.4 million is limited to $142.4 million (other than with respect to the indemnification of environmental matters to which there is no limit) due to the performance of some of the underlying obligations that were guaranteed. The discounted probability-weighted liability under the guarantees and indemnifications as of March 31, 2007, was $0.3 million, resulting in a corresponding reduction in the available credit under Cleco’s credit facility, which was determined in accordance with the facility’s definition of a contingent obligation. The contingent obligation reduces the amount available under the credit agreement by an amount equal to the reasonably anticipated liability in respect of the contingent obligation as determined in good faith.
 
26
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
For additional information on this guarantee, see Note 9 — “Disclosures about Guarantees.”
In November 2004, Cleco completed the sale of substantially all of the assets of Cleco Energy. Cleco Corporation provided guarantees to the buyers of Cleco Energy’s assets for the payment and performance of the indemnity obligations of Cleco Energy. The aggregate amount of the guarantees is $1.4 million, and the guarantees expire in 2009.
If Evangeline fails to perform certain obligations under its tolling agreement, Cleco Corporation will be required to make payments to the Evangeline Tolling Agreement counterparty. Cleco Corporation’s obligation under the Evangeline commitment is in the form of a standby letter of credit from investment grade banks and is limited to $15.0 million. Rating triggers do not exist in the Evangeline Tolling Agreement. Cleco expects Evangeline to be able to meet its obligations under the tolling agreement and does not expect Cleco Corporation to be required to make payments to the counterparty. However, under the covenants associated with Cleco Corporation’s credit facility, the entire net amount of the Evangeline commitment reduces the amount that can be borrowed under the credit facility. The letter of credit for Evangeline is expected to be renewed annually until 2020.
In March 2005, Cleco Corporation issued a guarantee to Central Mississippi Generating Company, LLC for Attala’s obligations and liabilities under the purchase and sale agreement between Central Mississippi Generating Company, LLC and Attala. On January 20, 2007, the guarantee expired. In addition, in January 2006, Cleco Corporation provided a $0.5 million guarantee to Entergy Mississippi for Attala’s obligations under the Interconnection Agreement. This guarantee has no time limit.
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 $0.5 million letter of credit, an amount equal to 110% of the average losses over the previous three years, as surety.
As part of the Lignite Mining Agreement entered into in 2001, 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, 2007, Cleco Power’s 50% exposure for this obligation was approximately $10.9 million. The lignite mining contract is in place until 2011 and does not affect the amount Cleco Corporation can borrow under its credit facility.
In December 2006, Cleco Power issued a standby letter of credit to the Louisiana Department of Wildlife and Fisheries in order to obtain a permit to allow for dredging operations at the Rodemacher Unit 3 site. The letter of credit was for approximately $0.1 million and expired on April 1, 2007.
The following table summarizes the expected termination date of the guarantees and standby letters of credit discussed above:
                   
 
 
 
 
 
 
 
 
AT MARCH 31, 2007
 
 
 
 
 
AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
 
 
 
NET
 
 
 
 
 
 
 
MORE
 
 
 
AMOUNT
 
LESS THAN
 
 
 
 
 
THAN
 
(THOUSANDS)
 
COMMITTED
 
ONE YEAR
 
1-3 YEARS
 
3-5 YEARS
 
5 YEARS
  
Guarantees
  
$
155,220
  
$
-
  
$
1,400
  
$
110,920
  
$
42,900
  
Standby letters of credit
    
15,610
    
610
    
-
    
-
    
15,000
  
Total commercial commitments
  
$
170,830
  
$
610
  
$
1,400
  
$
110,920
  
$
57,900
  

Acadia
In May 2005, a detailed review of the gas and electric metering at the Acadia plant resulted in the discovery of a potential electric metering error whereby Acadia unknowingly generated excess power to its electric interconnections for the period beginning June 1, 2002, and ending May 31, 2005. Acadia has made a claim against Cleco Power for the delivery of the excess generation for which it has not received compensation. Cleco Power has evaluated the claim and communicated to Acadia that to the extent any unmetered power was generated, Entergy received the predominant benefit of that power and therefore Acadia’s claim, if any, is primarily against Entergy rather than Cleco Power. Acadia has responded, insisting that its claim against Cleco Power is valid. As such, in a letter dated July 19, 2006, Acadia demanded compensation from Cleco Power totaling approximately $4.5 million, allegedly representing the value of the energy delivered. Cleco Power continues to assert that Acadia’s claim is against Entergy, not Cleco Power. The three parties are attempting to resolve the dispute.
In December 2005, the Calpine Debtors filed for protection under Chapter 11 of the U.S. Bankruptcy Code in the Calpine Debtors Bankruptcy Court. For additional information about the Calpine Bankruptcy, see Note 15 — “Calpine Bankruptcy” and for more information on the proposed Acadia settlement agreement, see Note 16 — “Subsequent Event.”

Other Contingencies
 
General Electric Services Corporation
Cleco Power has entered into an operating lease agreement with General Electric Services Corporation for leasing of railcars in order to transport coal deliveries to its Rodemacher Power Station. The lease contains a provision for early termination, along with an associated termination fee. The termination provision can only be exercised in December 2010. If exercised by Cleco Power, the termination fee would be approximately $1.4 million. At this time, Cleco Power has no plans to early terminate this lease.
 
27
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
CBL Capital Corporation
Cleco Power has entered into an operating lease agreement with CBL Capital Corporation. This is a master leasing agreement for company vehicles and other equipment. The lease contains a provision for early termination, along with an associated termination fee. At any time during the lease, Cleco Power may terminate the agreement. The termination fee is based upon the unamortized residual value of the equipment under lease at the end of the month of termination. The fee is decreased by any sale proceeds obtained by CBL Capital Corporation. Cleco Power would be liable for 87% of the termination fee net of any sale proceeds. Cleco Power’s maximum obligation at March 31, 2007, is approximately $2.3 million. At this time, Cleco Power has no plans to terminate this lease prior to expiration of the lease term.
 
FERC Staff Investigation
In November 2005, after a review of Cleco’s October 2005 quarterly compliance report, the FERC Staff initiated a preliminary, non-public investigation into certain representations made by Cleco. In response to data requests from the FERC Staff, Cleco provided information regarding those representations as well as compliance with the Code of Conduct and Compliance Plan contained in the Consent Agreement. The information primarily concerns the possible sharing of employees and information among Cleco’s subsidiaries, as well as the accuracy of information furnished to the FERC Staff in connection with reporting on compliance with the Consent Agreement. Discussions with the FERC Staff are ongoing. Management is unable to predict the results of the outcome of the investigation which could have a material adverse effect on the Registrants’ results of operations and cash flows.
 
Fuel Audit
On July 14, 2006, the LPSC informed Cleco Power that it was planning to conduct a periodic fuel audit. The audit commenced on July 26, 2006, and included fuel adjustment clause filings for January 2003 through December 2004. Cleco Power has produced to the LPSC Staff all of the requested information. The audit is pursuant to the Fuel Adjustment Clause General Order issued November 6, 1997, in Docket No. U-21497 which anticipates that an audit will be performed not less than every other year. The LPSC Staff is performing this review, and Cleco Power expects a preliminary report to be issued when the review is complete. Management is unable to predict the results of the LPSC audit, which could require Cleco Power to refund previously recovered revenue and could result in a significant material adverse effect on the Registrants’ results of operations, financial condition, and cash flows.
 
Other
Cleco has accrued for liabilities to third parties, employee medical benefits, storm damages, and deductibles under insurance policies that it maintains on major properties, primarily generation stations and transmission substations.
Consistent with regulatory treatment, annual charges to operating expenses to provide a reserve for future storm damages are based upon the average amount of noncapital, uninsured storm damages experienced by Cleco Power during the previous six years, excluding costs for Hurricanes Katrina and Rita for which Cleco Power has requested authorization from the LPSC to recover.
 
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.
 
Williams
The credit ratings of the senior unsecured debt of The Williams Companies, Inc. (Moody’s - Ba2; Standard & Poor’s - BB), the parent company of Williams under the Evangeline Tolling Agreement, remains below investment grade. The following list discusses some possible adverse consequences if Williams should fail to perform its obligations under the Evangeline Tolling Agreement:
 
§  
If Williams’ failure to perform constituted a default under the tolling agreement, the holders of the Evangeline bonds would have the right to declare the entire outstanding principal amount ($180.9 million at March 31, 2007) and interest to be immediately due and payable, which could result in:
§  
Cleco seeking to refinance the bonds, the terms of which may be less favorable than existing terms;
§  
Cleco causing Evangeline to seek protection under federal bankruptcy laws; or
§  
the trustee of the bonds foreclosing on the mortgage and assuming ownership of the Evangeline plant;
§  
Cleco may not be able to enter into agreements in replacement of the Evangeline Tolling Agreement on terms as favorable as that agreement or at all;
§  
Cleco’s equity investment in Evangeline may be impaired, requiring a write-down to its fair market value, which could be substantial; and
§  
Cleco’s credit ratings could be downgraded, which would increase borrowing costs and limit sources of financing.
 
CES
In December 2005, the Calpine Debtors filed for protection under Chapter 11 of the U.S. Bankruptcy Code in the Calpine Debtors Bankruptcy Court and filed a motion with the court seeking to reject the Calpine Tolling Agreements. For additional information about the Calpine bankruptcy, see Note 15 — “Calpine Bankruptcy” and for more information on the proposed Acadia settlement agreement, see Note 16 — “Subsequent Event.”
 
28
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
Although neither Acadia nor Cleco were required to record an impairment of their assets or equity investment at March 31, 2007, future events could cause the valuation of those assets or equity investment to be higher than market whereby an impairment would be required and Cleco’s financial condition would be adversely affected.
 
Other
Financing for operational needs and construction requirements is dependent upon the cost and availability of external funds from capital markets and financial institutions. Access to funds is dependent upon factors such as general economic conditions, regulatory authorizations and policies, the credit ratings of Cleco Corporation and Cleco Power, the cash flows from routine operations and the credit ratings of project counterparties. If Cleco Corporation’s credit rating was to be downgraded by Moody’s or by Standard & Poor’s, Cleco Corporation would be required to pay additional fees and higher interest rates under its bank credit and other debt agreements.
 
Cleco Power
Cleco Power supplies a portion 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. Because of 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.
Financing for operational needs and construction requirements is dependent upon the cost and availability of external funds from capital markets and financial institutions. Access to funds is dependent upon factors such as general economic conditions, regulatory authorizations and policies, the credit ratings of Cleco Corporation and Cleco Power, the cash flows from routine operations and the credit ratings of project counterparties. If Cleco Power’s credit rating was to be downgraded by Moody’s or by Standard & Poor’s, Cleco Power would be required to pay additional fees and higher interest rates under its bank credit and other debt agreements.
Under the terms of the Amended EPC Contract, 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 9 — Disclosures about Guarantees
Cleco Corporation and Cleco Power 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 FIN 45. Guarantees issued or modified after December 31, 2002, that fall within the initial recognition scope of FIN 45 are required to be recorded as a liability. Outstanding guarantees that fall within the disclosure scope of FIN 45 are required to be disclosed for all accounting periods ending after December 15, 2002.
Guarantees and indemnifications were issued in connection with the sale of the generation assets to Entergy Louisiana by Perryville. These guarantees and indemnifications fall within the recognition scope of FIN 45 because they relate to the past performance, indemnity, representation, and warranty obligations of the disposed assets and also contain provisions requiring payment for potential damages. The potential length of these liabilities range from a five-year life to an indefinite life. Each indemnification and guarantee was assigned a probability and an estimate of potential damages. The maximum aggregate potential damages under the guarantees and indemnifications are $42.4 million (excluding maximum aggregate potential damages of $100.0 million for discharge of project debt discussed in more detail below and the indemnification of environmental matters to which there is no limit). On June 30, 2005, Perryville paid all interest and principal owed under the Senior Loan Agreement, and on July 19, 2005, it exercised offset rights against MAI to satisfy its obligations of $98.7 million under the Subordinated Loan Agreement. As a result, it is unlikely that Cleco Corporation will have any other liabilities which would give rise to indemnity claims against Perryville and trigger any actual obligation under the $100.0 million portion of the guarantee which expires on June 30, 2010. The discounted probability-weighted liability under the guarantees and indemnifications as of March 31, 2007, calculated in accordance with FIN 45, was $0.3 million.
Guarantees and indemnifications were issued in connection with the asset sales of Cleco Energy's oil and gas properties and natural gas pipelines. These guarantees and indemnifications fall within the recognition scope of FIN 45, because they relate to the past performance obligations of the disposed assets and also contain provisions requiring payment for potential damages. The potential liabilities expire either after a two- or five-year life. Each indemnification and guarantee was assigned probabilities and estimates of potential damages. On September 15, 2006, the portion of the guarantee with a two-year life expired. The maximum aggregate potential payment under the guarantees and indemnifications is $1.2 million. The discounted probability-weighted liability under the guarantees and indemnifications as of March 31, 2007, was less than $0.1 million. The buyers of the Cleco Energy assets would be entitled to amounts under the guarantees and indemnifications due to breach or default of performance of Cleco Energy under their respective sale agreements. Cleco Corporation has guaranteed Cleco Energy’s indemnification obligations under the sale agreements. Maximum potential payments under the Cleco Corporation
 
29
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
guarantees are $1.4 million but are not within the recognition scope of FIN 45.
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 obligations as described above with respect to its managers, officers, agents, and employees.
Cleco Corporation has issued guarantees and a letter of credit to support the activities of Perryville, Attala, and Evangeline. These commitments are not within the scope of FIN 45, since these are guarantees of performance by wholly owned subsidiaries. For information regarding these commitments, see Note 8 — “Litigation and Other Commitments and Contingencies — Off-Balance Sheet Commitments.”
Under the Lignite Mining Agreement, Cleco Power and SWEPCO have agreed to pay the lignite miner’s loan and lease principal obligation. For information on the Lignite Mining Agreement, see Note 8 — “Litigation and Other Commitments and Contingencies — Off-Balance Sheet Commitments.”
Generally, neither Cleco Corporation nor Cleco Power has recourse that would enable them to recover amounts paid under the guarantees. 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.
 
Note 10 — Preferred Stock
Within the ESOP, each share of Cleco Corporation 8.125% Convertible Preferred Stock Series 1991 (ESOP preferred stock) is convertible into 9.6 shares of Cleco Corporation common stock (Cleco common stock). The annual dividend rate on a share of ESOP preferred stock is generally the higher of $8.125 per share or 9.6 times the annual dividend rate for a share of Cleco common stock.
At December 31, 2006, the ESOP had allocated 190,635 shares of ESOP preferred stock to 401(k) Plan participants. In March 2007, in order to comply with provisions of the Pension Protection Act of 2006, 190,372 shares of ESOP preferred stock were converted into 1.8 million shares of Cleco common stock. The ESOP trustee holds the newly converted shares of Cleco common stock on behalf of the 401(k) Plan participants.
As a result of this conversion, total shareholders’ equity reported on Cleco Corporation’s Condensed Consolidated Balance Sheet at March 31, 2007, did not change. Cleco Corporation recorded a $19.1 million reduction in preferred stock with a corresponding increase in common shareholders’ equity.
 
Note 11 — Pension Plan and Employee Benefits
 
Pension Plan and Other Benefits Plan
Most employees are covered by a noncontributory, 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 Internal Revenue Service’s full funding limitation. No contributions to the pension plan were made during the three months ended March 31, 2007. During 2007, a contribution is not expected to be required by funding regulations. A discretionary contribution may be made during 2007; however, the decision by Management to make a contribution and the amount, if any, has not been determined. 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, 2007, and 2006, are as follows:
           
 
 
PENSION BENEFITS
 
OTHER BENEFITS
 
 
 
FOR THE THREE MONTHS ENDED MARCH 31,
 
(THOUSANDS)
 
2007
 
2006
 
2007
 
2006
  
Components of periodic benefit  costs
                  
Service cost
  
$
1,910
  
$
1,852
  
$
355
  
$
393
  
Interest cost
   
3,863
    
3,704
    
460
    
432
  
Expected return on plan assets
    
(4,748
)
  
(4,292
)
  
-
    
-
  
Transition obligation
   
-
    
-
    
5
    
5
  
Prior period service cost
   
212
    
247
    
(515
)
  
(506
)
Net loss
   
468
    
129
    
250
    
212
  
Net periodic benefit cost
  
$
1,705
  
$
1,640
  
$
555
  
$
536
  
 
Since Cleco Power is the pension plan sponsor and the related trust holds the assets, the prepaid benefit cost 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 expense of the pension plan related to Cleco Corporation’s other subsidiaries for the three months ended March 31, 2007, and 2006, was $0.5 million and $0.6 million, respectively.
Cleco Corporation is the plan sponsor for the other benefits. There are no assets set aside in a trust, and the liabilities are reported on the individual subsidiaries’ financial statements. The expense related to other benefits reflected on Cleco Power’s Condensed Statements of Income for the three months ended March 31, 2007, and 2006, was $0.5 million.
 
30
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
SERP
Certain key executives and key managers 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 last 60 months prior to retirement, reduced by benefits received from any other defined benefit pension 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 SERP participants’ life insurance benefits, as well as future SERP payments. However, since this 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. No contributions to the SERP were made during the three months ended March 31, 2007, and 2006. 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)
 
2007
 
2006
  
Components of periodic benefit costs
          
Service cost
  
$
290
  
$
340
  
Interest cost
    
438
    
368
  
Prior period service cost
    
12
    
14
  
Net loss
    
243
    
202
  
Net periodic benefit cost
  
$
983
  
$
924
  
 
The SERP has no assets, and liabilities are reported on the individual subsidiaries’ financial statements. The expense related to the SERP reflected on Cleco Power’s Condensed Statements of Income for the three months ended March 31, 2007, and 2006, was $0.3 million.
 
401(k) Plan/ESOP
Most employees are eligible to participate in the 401(k) Plan, which was amended in April 1991 to include a leveraged ESOP. The ESOP was established with 300,000 shares of ESOP preferred stock which served as Cleco Corporation’s match to employees’ 401(k) Plan contributions and funded dividend payments on allocated shares. Compensation expense related to the 401(k) Plan is based upon the value of the shares of ESOP preferred stock allocated to 401(k) Plan participants and the amount of interest incurred by the ESOP, less dividends on unallocated shares held by the ESOP.
At March 31, 2006, substantially all of the shares of ESOP preferred stock were fully allocated to current and former 401(k) Plan participants. Beginning April 1, 2006, Cleco Corporation made matching contributions to, and funded dividend reinvestments by, 401(k) Plan participants with Cleco common stock. Compensation expense related to the newly issued common shares is based upon the fair market value of the common stock issued to 401(k) Plan participants. At March 31, 2007, and December 31, 2006, Cleco Corporation had issued 186,207 and 140,189 shares of Cleco common stock, respectively, to 401(k) Plan participants, including dividend reinvestments.
On March 26, 2007, the ESOP trustee converted all outstanding 190,372 shares of ESOP preferred stock into 1.8 million shares of Cleco common stock. For more information on the conversion, see Note 10 — “Preferred Stock.”
The table below contains information about the 401(k) Plan and the ESOP:
       
   
FOR THE THREE MONTHS ENDED MARCH 31,
  
(THOUSANDS)
  
2007
  
2006
  
401(k) Plan expense
  
$
899
  
$
100
  
Dividend requirements to ESOP on convertible preferred stock
  
$
411
  
$
449
  
Interest incurred by ESOP on its indebtedness
  
$
-
  
$
9
  
 
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 the three months ended March 31, 2007, and 2006, was $0.2 million and less than $0.1 million, respectively. The expense related to the dividend requirements on the shares of ESOP preferred stock is reflected on Cleco Corporation’s Condensed Consolidated Statements of Income for the three months ended March 31, 2007, and 2006.
 
Note 12 — 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, 2007, and March 31, 2006.
   
 
FOR THE THREE MONTHS ENDED MARCH 31,
 
2007
  
2006
Cleco Corporation
19.9%
  
33.3%
Cleco Power
20.2%
  
33.7%
 
Cleco Corporation’s and Cleco Power’s effective income tax rates for the three months ended March 31, 2007, decreased compared to the three months ended March 31, 2006, as shown in the chart above. A common contributing factor includes the flow-through of tax benefits associated with AFUDC equity recorded as a result of the construction of Rodemacher Unit 3. Tax rates also were affected by the relative size of pre-tax income related to this item.
Effective January 1, 2007, Cleco adopted the provisions of FIN 48 which provides guidance on accounting for uncertain tax positions. During 2006, Cleco included all interest related to uncertain tax positions as a component of tax expense and taxes payable. Subsequent to the adoption of FIN 48, Cleco classified all interest related to uncertain tax positions as a component of interest expense and interest payable. During the first quarter of 2006, $0.7 million of interest expense was included in tax expense and was not reclassified in the financial statements. The total amount of interest associated with tax positions recognized on the balance sheets of Cleco Corporation and Cleco Power as of the date of adoption was $16.7 million and $10.2 million, respectively, and $19.1 million and $12.2 million as of March 31, 2007, respectively. There was no additional interest expense recognized at the date of
 
31
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
adoption. The total amount of unrecognized tax benefits for Cleco Corporation and Cleco Power as of the date of adoption was $62.3 million and $30.9 million, respectively, and $97.9 million and $66.2 million as of March 31, 2007, respectively. Approximately $33.9 million of the change was mainly due to adjustments taken on the 2005 federal income tax return for an indirect cost study and a casualty loss deduction. Approximately $1.5 million was due to a request for refund filed with the Internal Revenue Service due to the deduction for the tax life of street lights and meters from a 1997 cost segregation study. Due to settlement discussions with the Internal Revenue Service, management believes that some of these unrecognized benefits may be recognized, resulting in an approximate $1.0 million benefit to the effective tax rate.
The federal income tax years that remain subject to examination by the Internal Revenue Service are 2001-2006. The Louisiana state income tax years that remain subject to examination by the Louisiana Department of Revenue are 1998-2006.
During the three months ended March 31, 2007, there were no decreases in unrecognized tax benefits relating to settlements or a lapse of the applicable statute of limitation, and there were no material changes to tax years that remain subject to examination by major tax jurisdictions.
 
Note 13 — 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, 2007, approximately 97% of Cleco Power’s total fuel cost was regulated by the LPSC, while the remainder was regulated by the FERC. Deferred fuel and purchased power costs recorded at March 31, 2007, and December 31, 2006, were under-recoveries of $34.9 million and $77.4 million, respectively, and are scheduled to be collected from customers in future months. The $42.5 million decrease in the unrecovered costs was primarily the result of a $47.1 million increase in the market value of open natural gas hedge positions along with $4.5 million of lower losses in closed natural gas hedge positions, both due to increases in natural gas prices since December 31, 2006. The increase in market value and lower losses were partially offset by the deferral of $9.1 million in additional fuel and purchased power costs.
For additional information on Cleco Power’s treatment of natural gas hedges, see Note 1 — “Summary of Significant Accounting Policies — Risk Management.”
 
Note 14 — Affiliate Transactions
Cleco has affiliate balances that were not eliminated as of March 31, 2007. The balances were not eliminated due to the use of the equity method of accounting for Evangeline, Perryville, Attala, and Acadia. For information on the Evangeline, Perryville, Attala, and Acadia equity investments, see Note 4 — “Equity Investment in Investees.” At March 31, 2007, the payable to Evangeline was $6.0 million, and the payable to Perryville was $13.4 million. Also, at March 31, 2007, the receivable from Evangeline was $0.8 million, the receivable from Perryville was $9.6 million, and the receivable from Acadia was $3.6 million.
Cleco Power has affiliate balances that are payable to or due from its affiliates. At March 31, 2007, the payable to Support Group was $8.1 million, the payable to Cleco Corporation was $10.6 million, and the payable to other affiliates was less than $0.1 million. Also, at March 31, 2007, the receivable from Cleco Corporation was $2.7 million, the receivable from Support Group was $2.2 million, and the receivable from other affiliates was less than $0.1 million.
 
Note 15 — Calpine Bankruptcy
 
Bankruptcy Proceedings
In December 2005, the Calpine Debtors filed for protection under Chapter 11 of the U.S. Bankruptcy Code in the Calpine Debtors Bankruptcy Court. Subsequently, the Calpine Debtors filed a motion with the bankruptcy court seeking to reject the Calpine Tolling Agreements in addition to six other power supply contracts with other entities. The rejection motion was referred to the U.S. District Court for the Southern District of New York, and in January 2006, a federal judge dismissed the motion. The Calpine Debtors have appealed the decision to the U.S. Court of Appeals for the Second Circuit, where it remains pending.
In March 2006, Acadia filed a motion with the Calpine Debtors Bankruptcy Court to compel CES to perform under the Calpine Tolling Agreements, and to pay all amounts due under such agreements since the commencement of the Calpine Debtors’ bankruptcy cases. On March 22, 2006, the Calpine Debtors Bankruptcy Court approved amendments to each of the Calpine Tolling Agreements which permitted Acadia to suspend its obligations under those tolling agreements in view of CES’ non-performance. Acadia has postponed indefinitely its request for a hearing on the motion to compel pending the outcome of the proposed settlement agreement between Cleco Corporation and Calpine.
 
Outstanding Claims
As of March 31, 2007, Acadia had invoiced CES a total of $86.2 million for obligations performed under the Calpine Tolling Agreements.
       
   
(THOUSANDS)
  
Pre-petition claims
      
December 2005
  
$
3,581
  
Post-petition claims
        
December 2005
    
1,962
  
Twelve months ended December 31, 2006
    
64,478
  
Three months ended March 31, 2007
    
16,143
  
Total
 
$
86,164
  
 
As of March 31, 2007, Acadia has recorded a reserve for uncollectible accounts of $71.2 million, net of the full amount drawn by APH during 2006 against the $15.0 million letter of credit issued by Calpine.
 
32
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
Other
For information regarding a dispute over electric metering at Acadia, see Note 8 — “Litigation and Other Commitments and Contingencies — Acadia.”
For a discussion of a preliminary settlement reached between Cleco Corporation and Calpine associated with Calpine’s bankruptcy filing and its effect on the Acadia facility, see Note 16 — “Subsequent Event.”
 
Note 16 — Subsequent Event
On April 23, 2007, Cleco announced that a settlement had been reached with Calpine that resolves issues related to the Acadia power plant. The settlement is subject to approval by the Calpine Debtors Bankruptcy Court.
The first part of the settlement involves claims of Acadia against CES, which is the counterparty to the suspended Calpine Tolling Agreements for CES’ breaches of such agreements, and Calpine’s guarantee of CES’ obligations thereunder. Under the proposal, APH will receive a pre-petition general unsecured claim against each of Calpine and CES for $85.0 million (which is net of draws made by APH under a letter of credit in the aggregate amount of $15.0 million), which represents APH’s share of Acadia’s allowed claims against each of CES and Calpine for $185.0 million on account of CES’s breaches of its obligations under the Calpine Tolling Agreements.
Additionally, APH has agreed to serve as the “stalking horse” bidder for Calpine’s membership interest in Acadia for $60.0 million plus assumed liabilities through a bankruptcy-court sponsored auction. APH’s $60.0 million offer, in effect, values an unencumbered 50% interest in the Acadia power plant at $145.0 million, taking into account the agreed value of certain priority distributions and payments due APH. The terms of the auction, which includes a $2.9 million breakup fee in favor of APH, are scheduled to be considered for approval at a bankruptcy court hearing on May 9, 2007. The auction process is expected to be completed in late July 2007. Until the auction process is complete, a third party marketer will continue to provide energy management services for the Acadia power plant.
If APH is not the successful bidder, APH will retain its 50% membership interest in Acadia and receive payment from the successful bidder in the amount of $85.0 million, which represents the agreed upon value of the priority distributions and payments due APH under the current Acadia agreement with Calpine. This $85.0 million payment is in addition to APH’s $85.0 million pre-petition general unsecured claims against Calpine and CES for CES’ non-performance under the Calpine Tolling Agreements.
Whether APH or another bidder is the successful purchaser at the auction, upon closing of the sale, a subsidiary of Cleco will assume operations and project management functions of the Acadia facility. At the closing of the sale APH will acquire, for an agreed value of $1.25 million (subject, in certain circumstances, to reduction), Calpine’s interest in the claim against Cleco Power regarding a potential electric metering error at the Acadia facility.
 
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, 2006, and Cleco Corporation’s and Cleco Power’s Condensed 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, 2007, and March 31, 2006.
 
OVERVIEW
Cleco is a regional energy services holding company that conducts substantially all of its business operations through its two principal operating business segments:
 
§  
Cleco Power, an integrated electric utility services subsidiary regulated by the LPSC and the FERC, among other regulators, which also engages in energy management activities; and
§  
Midstream, a merchant energy subsidiary regulated by the FERC, that owns and operates a merchant generation station and invests in a joint venture that owns and operates a merchant generation station.
 
While management believes that Cleco remains a strong company, Cleco continues to focus on several significant factors affecting Cleco Power and Midstream as described below.
 
Cleco Power
Many factors affect the opportunities, challenges, and risks of Cleco Power's primary business of selling electricity. These factors include the presence of a stable regulatory environment, which includes recovery of costs and maintenance of a competitive return on equity; the ability to achieve energy sales growth while containing costs; and the ability to recover costs related to growing demand and rising fuel prices and increasingly stringent regulatory and environmental standards.
As part of its plan to resolve long-term capacity needs, Cleco Power began construction of Rodemacher Unit 3 in May 2006, which, upon completion, will provide a portion of the utility’s future power supply needs and help stabilize customer fuel costs. The project’s capital cost, including carrying costs during construction, is estimated at $1.0 billion. Cleco Power anticipates the plant will be operational no later than the fourth quarter of 2009. For additional information, see “— Financial Condition — Liquidity and Capital Resources — Regulatory Matters — Rodemacher Unit 3.”
 
33
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
Cleco Power continues to evaluate a range of other power supply options for 2008 and beyond. As such, Cleco Power is continuing to update its IRP to look at future sources of supply. Cleco Power has issued a RFP to meet its 2008 capacity and energy requirements. Cleco Power also plans to release an additional RFP in 2007 to identify long-term resources to fill the needs forecasted by the latest IRP.
In 2005, Hurricanes Katrina and Rita caused catastrophic damage to the Gulf Coast region, including Cleco Power's service territory. Storm restoration costs from Hurricanes Katrina and Rita are currently estimated to total $158.7 million, a decrease from the original estimate of $161.8 million filed with the LPSC. In March 2007, Cleco Power and the LPSC Staff filed a settlement agreement allowing the recovery of $158.7 million of storm restoration costs. For additional information, see Item 1, “Financial Statements and Supplementary Data — Notes to the Unaudited Condensed Financial Statements — Note 2 — Regulatory Assets and Liabilities.”
Cleco Power is exploring the potential reimbursement of storm restoration costs from the U.S. Government to reduce the amount to be recovered from customers. In addition, Cleco Power is exploring the possibility of financing the storm restoration costs with tax-exempt bonds through the Gulf Opportunities Zone Act of 2005 (the Act). The Louisiana State Bond Commission has granted preliminary approval to Cleco Power for the issuance of up to $160.0 million of tax-exempt bonds under the Act. Cleco Power cannot predict with certainty that any reimbursement from the U.S. Government, securitization of costs, or any other financing will be given final approval, and if approved, the certainty that any such financing can be consummated.
 
Midstream
In December 2005, the Calpine Debtors filed for protection under Chapter 11 of the Bankruptcy Code and subsequently filed a motion with the Calpine Debtors Bankruptcy Court to reject the Calpine Tolling Agreements. In March 2006, Acadia and CES executed amendments to the Calpine Tolling Agreements, which were approved by the Calpine Debtors Bankruptcy Court, permitting Acadia to suspend its obligations under the agreements.
On April 23, 2007, Cleco announced that a settlement, subject to bankruptcy court approval, had been reached with Calpine that resolves issues surrounding the Calpine bankruptcy filing. Under the proposed settlement, APH will receive allowed unsecured claims against Calpine of $85.0 million in connection with the Calpine Tolling Agreements and Calpine’s guaranty of those agreements. Additionally, APH has agreed to purchase Calpine’s ownership interest in Acadia for $60.0 million, subject to any higher or better offers Calpine may receive in a bankruptcy court-sponsored auction. The auction process is anticipated to begin in May, with the bankruptcy auction expected in July. The terms of the auction will be considered at a May 9, 2007, bankruptcy court hearing. If APH is not the successful bidder, APH will retain its 50% ownership in Acadia and receive payment from the successful bidder in the amount of $85.0 million representing the value of its priority distributions from the partnership. In either outcome, a Cleco subsidiary will assume operations and project management functions of the Acadia facility. Until the auction process is complete, a third party marketer will continue to provide energy management services for the Acadia power plant. For additional information on Acadia and the Calpine bankruptcy, see Item 1, “Notes to the Unaudited Condensed Financial Statements — Note 15 — Calpine Bankruptcy” and Note 16 — “Subsequent Event.”
Cleco continues to assess the ongoing credit condition of the Evangeline Tolling Agreement counterparty, as Midstream’s merchant energy business is heavily dependent on the performance of this tolling agreement. For additional information on the risks associated with this tolling agreement counterparty, see Item 1, “Financial Statements and Supplementary Data — Notes to the Unaudited Condensed Financial Statements — Note 8 — Litigation and Other Commitments and Contingencies — Risks and Uncertainties.”
Effective February 1, 2007, the ownership interests of Midstream’s transmission interconnection facilities were transferred to Cleco Corporation. In accordance with SFAS No. 131, the net operating results for Midstream for the first quarter of 2006 have been adjusted to reflect this organizational change.
 
Comparison of the Three Months Ended March 31, 2007, and 2006
 
Cleco Consolidated
           
 
 
 
  
FOR THE THREE MONTHS ENDED MARCH 31,
  
           
FAVORABLE/(UNFAVORABLE)
  
(THOUSANDS)
  
2007
  
2006
  
VARIANCE
  
CHANGE
  
Operating revenue, net
  
$
223,750
  
$
223,418
  
$
332
    
0.15
 %
Operating expenses
    
206,096
    
197,445
    
(8,651
)
  
(4.38
)%
Operating income
 
$
17,654
  
$
25,973
  
$
(8,319
)
  
(32.03
)%
Allowance for other funds used during construction
  
$
5,131
  
$
669
  
$
4,462
    
666.97
 %
Equity (loss) income from investees
 
$
(1,399
)
$
373
  
$
(1,772
)
  
(475.07
)%
Other expense
  
$
1,266
  
$
328
  
$
(938
)
  
(285.98
)%
Interest charges
  
$
11,987
  
$
10,949
  
$
(1,038
)
  
(9.48
)%
Federal and state income taxes
  
$
2,143
  
$
6,113
  
$
3,970
    
64.94
 %
Net income applicable to common stock
  
$
8,223
  
$
11,679
  
$
(3,456
)
  
(29.59
)%
 
Consolidated net income applicable to common stock decreased $3.5 million, or 29.6%, in the first quarter of 2007 compared to the first quarter of 2006 primarily due to decreased Cleco Power, Midstream, and corporate earnings.
Operating expenses increased $8.7 million, or 4.4%, in the first quarter of 2007 compared to the first quarter of 2006 primarily due to increased depreciation expense and other operations and maintenance expenses at Cleco Power.
Allowance for other funds used during construction increased $4.5 million, or 667.0%, in the first quarter of 2007 compared to the same period of 2006 primarily due to increased construction activity at Rodemacher Unit 3.
Equity income from investees decreased $1.8 million, or 475.1%, in the first quarter of 2007 compared to the same period of 2006 primarily due to decreased equity earnings at
 
34
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
APH, partially offset by increased equity earnings at Evangeline.
Other expense increased $0.9 million, or 286.0%, in the first quarter of 2007 compared to the same period of 2006 primarily due to increased corporate reserves.
Interest charges increased $1.0 million, or 9.5%, in the first quarter of 2007 compared to the same period of 2006 primarily due to the accrual of interest related to uncertain tax positions at Cleco Power.
Federal and state income taxes decreased $4.0 million, or 64.9%, in the first quarter of 2007 compared to the same period of 2006. The decrease was due to the flow-through of tax benefits associated with AFUDC equity recorded as a result of the construction of Rodemacher Unit 3.
Results of operations for Cleco Power and Midstream are more fully described below.
 
Cleco Power
Cleco Power’s net income in the first quarter of 2007 decreased $1.6 million, or 11.5%, compared to the first quarter of 2006. Contributing factors include:
 
§  
higher other operations and maintenance expenses,
§  
absence of favorable customer credit adjustments,
§  
higher depreciation expense,
§  
lower interest income, and
§  
higher interest charges.
 
These were partially offset by:
 
§  
higher base revenue,
§  
higher allowance for other funds used during construction,
§  
higher other operations revenue, and
§  
lower effective income tax rate.
 
           
 
 
 
 
FOR THE THREE MONTHS ENDED MARCH 31,
 
 
 
 
 
  
 
FAVORABLE/(UNFAVORABLE)
 
(THOUSANDS)
 
2007
 
 2006
 
VARIANCE
 
CHANGE
  
Operating revenue
                   
Base
  
$
78,075
  
$
67,898
  
$
10,177
    
14.99
 %
Fuel cost recovery
    
134,945
    
143,091
    
(8,146
)
  
(5.69
)%
Electric customer credits
    
-
    
4,382
    
(4,382
)
  
*
  
Other operations
    
9,260
    
6,549
    
2,711
    
41.40
 %
Affiliate revenue
    
12
    
12
    
-
    
*
  
Intercompany revenue
    
501
    
500
    
1
    
0.20
 %
Operating revenue, net
    
222,793
    
222,432
    
361
    
0.16
 %
Operating expenses
                          
Fuel used for electric  generation - recoverable
    
53,367
    
46,151
    
(7,216
)
  
(15.64
)%
Power purchased for utility  customers - recoverable
    
81,554
    
96,967
    
15,413
    
15.90
 %
Non-recoverable fuel and  power purchased
    
4,722
    
5,077
    
355
    
6.99
 %
Other operations
    
25,613
    
17,622
    
(7,991
)
  
(45.35
)%
Maintenance
    
9,727
    
5,347
    
(4,380
)
  
(81.92
)%
Depreciation
    
19,761
    
15,225
    
(4,536
)
  
(29.79
)%
Taxes other than income taxes
    
8,902
    
8,881
    
(21
)
  
(0.24
)%
Total operating expenses
    
203,646
    
195,270
    
(8,376
)
  
(4.29
)%
Operating income
  
$
19,147
  
$
27,162
  
$
(8,015
)
  
(29.51
)%
Interest income
  
$
1,406
  
$
2,336
  
$
(930
)
  
(39.81
)%
Allowance for other funds used during construction
  
$
5,131
  
$
669
  
$
4,462
    
666.97
 %
Interest charges
  
$
10,044
  
$
8,979
  
$
(1,065
)
  
(11.86
)%
Federal and state income taxes
  
$
3,116
  
$
7,057
  
$
3,941
    
55.85
 %
Net income
 
$
12,276
  
$
13,873
  
$
(1,597
)
  
(11.51
)%
* Not meaningful
                          

       
 
 
FOR THE THREE MONTHS ENDED MARCH 31,
 
 
(MILLION kWh)
 
 
2007
 
 
2006
 
FAVORABLE/
(UNFAVORABLE)
  
Electric sales
              
Residential
    
842
    
750
    
12.27
 %
Commercial
    
543
    
407
    
33.42
 %
Industrial
    
710
    
692
    
2.60
 %
Other retail
    
33
    
131
    
(74.81
)%
Total retail
    
2,128
    
1,980
    
7.47
 %
Sales for resale
    
102
    
117
    
(12.82
)%
Unbilled
    
(70
)
  
(82
)
  
14.63
 %
Total retail and wholesale customer sales
    
2,160
    
2,015
    
7.20
 %

       
 
 
FOR THE THREE MONTHS ENDED MARCH 31,
  
 
(THOUSANDS)
  
 
2007
  
 
2006
  
FAVORABLE/
(UNFAVORABLE)
  
Electric sales
              
Residential
  
$
33,265
  
$
30,340
    
9.64
 %
Commercial
    
22,295
    
16,946
    
31.56
 %
Industrial
    
13,634
    
13,383
    
1.88
 %
Other retail
    
1,440
    
5,497
    
(73.80
)%
Storm surcharge
    
5,931
    
-
    
*
  
Total retail
    
76,565
    
66,166
    
15.72
 %
Sales for resale
    
3,887
    
4,240
    
(8.33
)%
Unbilled
    
(2,377
)
  
(2,508
)
  
5.22
 %
Total retail and wholesale customer sales
  
$
78,075
  
$
67,898
    
14.99
 %
* Not meaningful
                    
 
 
35
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
Cleco Power’s residential customers’ demand for electricity largely is affected by weather. Weather generally is measured in cooling degree-days and heating degree-days. A cooling degree-day is an indication of the likelihood that a consumer will use air conditioning, while a heating degree-day is an indication of the likelihood that a consumer will use heating. An increase in heating degree-days does not produce the same increase in revenue as an increase in cooling degree-days, because alternative heating sources are more available. 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 temperature data collected by the National Oceanic and Atmospheric Administration to determine degree-days.
               
 
          
FOR THE THREE MONTHS ENDED MARCH 31,
  
               
2007 CHANGE
  
   
2007
  
2006
  
NORMAL
  
PRIOR YEAR
 
NORMAL
  
Heating degree-days
    
869
    
688
    
977
    
26.31
%
  
(11.05
)%
Cooling degree-days
    
112
    
110
    
70
    
1.82
%
  
60.00
 %
 
Base
Base revenue during the first quarter of 2007 increased $10.2 million, or 15.0%, compared to the same period in 2006. The increase primarily was due to the recovery of storm restoration costs through a monthly customer surcharge that began in May 2006. These storm-related costs are being amortized to expense based on the amounts collected monthly from customers through this surcharge. Also contributing to the increase in base revenue were higher retail and wholesale kWh sales, primarily from colder weather as compared to last winter. During 2007, Cleco Power is expected to begin providing service to expansions of current customers’ operations, as well as services to new commercial and new industrial customers. As a result of the expansions and new customers described above, the addition of 13 MWs, which approximates $1.4 million of base revenue annually, is expected during 2007. This addition partially offsets the loss of customers described below.
In late January 2007, one of Cleco Power’s largest industrial customers closed one of its three wood product plants. The closure of the plant was a result of a downturn in its product market, largely due to decreased home construction in various regions of the country. The load for this customer was 8 MW, generating base revenue of approximately $1.0 million annually.
In the third quarter of 2007, a large industrial customer is expected to begin operations of a cogeneration project. The project is a 15-MW unit on site fueled by waste heat. The project will displace the customer’s load of 12 MW, and the remaining 3 MW will be purchased by Cleco Power under a power purchase agreement. The annual base revenue loss from this customer is expected to be approximately $1.3 million. Another industrial customer is also expected to begin construction of a cogeneration project in 2007. This project is designed to displace all of the customer’s 38-MW load. Potential annual base revenue loss from this customer is expected to be approximately $5.0 million. The project is expected to be operational eighteen months after construction begins.
Cleco Power began selling fixed-priced power to a 30-MW wholesale customer on January 1, 2006. As a result of the fixed-price contract, the new customer is expected to increase base revenue while potentially diluting earnings in years 2007 and 2008. In years 2009 through 2012, Cleco Power anticipates earnings accretion related to this contract. For additional information on Cleco’s energy commodity activities, see Item 3, “Quantitative and Qualitative Disclosures about Market Risk — Risk Overview — Commodity Price Risks.”
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, 2006.
 
Fuel Cost Recovery
Fuel cost recovery revenue billed to customers during the first quarter of 2007 compared to the same period in 2006 decreased $8.1 million, or 5.7%, primarily due to decreases in the per-unit cost of power purchased for utility customers.  Partially offsetting the decrease were increased volumes of power purchased for utility customers and increases in the per-unit cost of fuel used for electric generation.  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 97% of Cleco Power’s total fuel cost is regulated by the LPSC, while the remainder is regulated by the FERC. Recovery of fuel adjustment clause costs is subject to refund until monthly approval is received from the LPSC. For information on Cleco Power’s ongoing 2003-2004 fuel audit, see Item 1, “Notes to the Unaudited Condensed Financial Statements — Note 8 — Litigation and Other Commitments and Contingencies — Fuel Audit.”
 
Electric Customer Credits
The $4.4 million change in electric customer credits is the result of the absence in the first quarter of 2007 of favorable adjustments made during the first quarter of 2006 related to prior RSP filing periods. The potential refunds associated with the RSP are based on results for each 12-month period ended September 30. For additional information on the accrual of electric customer credits, see Item 1, “Notes to the Unaudited Condensed Financial Statements — Note 7 — Electric Customer Credits.”
 
Other Operations
Other operations revenue increased $2.7 million, or 41.4%, in the first quarter of 2007 compared to the first quarter of 2006  
 
36
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
primarily due to a $1.5 million mark-to-market gain in the first quarter of 2007 as compared to a $1.9 million mark-to-market loss in the first quarter of 2006 relating to economic hedge transactions associated with fixed-price power being provided to a wholesale customer. This increase was partially offset by lower transmission services revenue. For information on Cleco’s energy commodity activities, see Item 3, “Quantitative and Qualitative Disclosures about Market Risk — Risk Overview — Commodity Price Risks.”
 
Operating Expenses
Operating expenses increased $8.4 million, or 4.3%, in the first quarter of 2007 compared to the same period of 2006. Fuel used for electric generation (recoverable) increased $7.2 million, or 15.6%, primarily due to higher per-unit costs and volumes of fuel used as compared to the same period of 2006. Power purchased for utility customers (recoverable) decreased $15.4 million, or 15.9%, largely due to lower per-unit costs of purchased power. Fuel used for electric generation and power purchased for utility customers generally are influenced by natural gas prices. However, other factors such as unscheduled outages, unusual maintenance or repairs, or other developments may affect fuel used for electric generation and power purchased for utility customers. Other operations expense increased $8.0 million, or 45.4%, primarily due to the absence in the first quarter of 2007 of the $3.5 million recognition of previously recorded storm restoration expenses as a regulatory asset as a result of the LPSC’s February 22, 2006, approval of Cleco Power’s request to recover these storm restoration costs. Also contributing to the increase were higher professional fees, higher employee benefit costs, and higher payroll and administrative expenses. Maintenance expenses during the first quarter of 2007 increased $4.4 million, or 81.9%, compared to the same period of 2006 primarily due to the absence of the $3.0 million recognition of previously recorded storm restoration expenses as a regulatory asset as a result of the LPSC’s February 22, 2006 order. Also contributing to the increase was more generating station maintenance work performed during the first quarter of 2007. Depreciation expense increased $4.5 million, or 29.8%, primarily as a result of $4.1 million of storm amortization costs and $0.4 million of normal recurring additions to fixed assets.
 
Interest Income
Interest income decreased $0.9 million, or 39.8%, during the first quarter of 2007 compared to the same period of 2006 primarily due to lower average investment balances.
 
Allowance for Other Funds Used During Construction
Allowance for other funds used during construction increased $4.5 million, or 667.0%, during the first quarter of 2007 compared to the same period of 2006 primarily due to increased construction activity at Rodemacher Unit 3. Allowance for other funds used during construction equaled 41.8% of Cleco Power’s net income for the first quarter of 2007, compared to 4.8% for the first quarter of 2006.
 
Interest Charges
Interest charges increased $1.1 million, or 11.9%, during the first quarter of 2007 compared to the same period of 2006 primarily due to the accrual of interest related to uncertain tax positions, which was previously reported in tax expense. For additional information, see Item 1, “Notes to the Unaudited Condensed Financial Statements — Note 12 — Income Taxes.”
 
Income Taxes
Income tax expense decreased $3.9 million, or 55.9%, during the first quarter of 2007 compared to the same period of 2006. Cleco Power’s effective income tax rate decreased from 33.7% to 20.2% during the first quarter of 2007 compared to the same period of 2006. The decrease in the rate was primarily due to the flow-through of tax benefits associated with AFUDC equity recorded as a result of the construction of Rodemacher Unit 3. Tax rates also were affected by the relative size of pre-tax income related to this item. Pre-tax income during the first quarter of 2007 decreased $5.5 million compared to the same period of 2006.
 
Midstream
Midstream’s net loss for the first quarter of 2007 increased $1.4 million, or 40.4%, compared to the first quarter of 2006. Factors affecting Midstream during the first quarter of 2007 are described below.
       
 
 
FOR THE THREE MONTHS ENDED MARCH 31,
 
 
 
 
 
 
 
FAVORABLE/(UNFAVORABLE)
 
(THOUSANDS)
 
2007
 
2006
 
VARIANCE
 
CHANGE
  
Operating revenue
                  
Other operations
  
$
7
  
$
4
  
$
3
    
75.00
 %
Affiliate revenue
    
986
    
1,050
    
(64
)
  
(6.10)
 %
Operating revenue
    
993
    
1,054
    
(61
)
  
(5.79
)%
Operating expenses
                          
Other operations
    
1,200
    
1,123
    
(77
)
  
(6.86
)%
Maintenance
    
460
    
502
    
42
    
8.37
 %
Depreciation
    
75
    
78
    
3
    
3.85
 %
Taxes other than income taxes
    
55
    
57
    
2
    
3.51
 %
Total operating expenses
    
1,790
    
1,760
    
(30
)
  
(1.70
)%
Operating loss
  
$
(797
)
$
(706
)
$
(91
)
  
(12.89
)%
Equity loss from investees
  
$
(1,827
)
$
(28
)
$
(1,799
)
  
*
  
Interest charges
  
$
5,042
  
$
4,231
  
$
(811
)
  
(19.17
)%
Federal and state income tax benefit
  
$
2,953
  
$
1,695
  
$
1,258
    
74.22
 %
Loss from discontinued operations
 
$
-
  
$
(87
)
$
87
    
*
  
Net loss
  
$
(4,714
)
$
(3,358
)
$
(1,356
)
  
(40.38
)%
* Not meaningful
                          
 
Equity Loss from Investees
Equity loss from investees increased $1.8 million in the first quarter of 2007 compared to the first quarter of 2006. The increase was due to a $2.3 million decrease in equity earnings at APH, partially offset by a $0.5 million increase at Evangeline. The decrease in earnings at APH primarily was due to the absence in the first quarter of 2007 of APH’s $2.8 million drawdown against the $15.0 million letter of credit issued by
 
 
37
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
Calpine. The increase at Evangeline primarily was due to lower gas and turbine maintenance expenses, as well as decreased heat rate penalties. For additional information on Evangeline and Acadia, see Item 1, “Notes to the Unaudited Condensed Financial Statements — Note 4 — Equity Investment in Investees.” As previously discussed, Midstream’s ownership interests in Perryville and Attala were transferred to Cleco Corporation effective February 1, 2007, and are no longer reported as equity income from investees on Midstream’s financial statements. In accordance with SFAS No. 131, operating results for the first quarter of 2006 have been adjusted to reflect this new structure. For additional information, see Item 1, “Notes to the Unaudited Condensed Financial Statements — Note 3 — Disclosures about Segments.”
 
Interest Charges
Interest charges increased $0.8 million, or 19.2%, during the first quarter of 2007 compared to the same period of 2006 primarily due to a higher interest rate and a higher balance on affiliate debt relating to APH’s investment in Acadia.
 
Income Taxes
Income tax benefit increased $1.3 million, or 74.2%, during the first quarter of 2007 compared to the same period of 2006. Midstream’s effective income tax rate increased from 34.1% to 38.5% during the first quarter of 2007 compared to the same period of 2006. The difference in the tax rate is primarily due to interest related to tax positions being accounted for as interest expense in 2007, compared to tax expense in 2006. Tax rates also were affected by the relative size of pre-tax income to this item. Pre-tax loss during the first quarter of 2007 increased $2.7 million compared to the same period of 2006.
 
FINANCIAL CONDITION
Liquidity and Capital Resources
 
General Considerations and Credit-Related Risks
 
Credit Ratings and Counterparties
At March 31, 2007, Moody’s outlook for both Cleco Corporation and Cleco Power was stable. Standard & Poor’s ratings outlook for both companies was negative due to continued uncertainties surrounding Cleco’s merchant energy activities and risks associated with the construction of Rodemacher Unit 3. If Cleco Corporation or Cleco Power’s credit rating were to be downgraded by Moody’s or Standard & Poor’s, Cleco Corporation and/or Cleco Power would be required to pay additional fees and higher interest rates under their bank credit and other debt agreements.
Under the terms of the Amended EPC Contract, 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 gas 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 gas, the changes in open power and natural 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. For additional information, as well as a discussion of other factors affecting Cleco’s financial condition relating to its credit ratings, the credit ratings of its counterparties, and other credit-related risks, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources — General Considerations and Credit-Related Risks — Credit Ratings and Counterparties” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2006.
 
Debt
At March 31, 2007, 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 various credit facilities, it would be unable to borrow additional funds under the facilities. Further, if Cleco Power were to default under its credit facility, Cleco Corporation would be considered in default under its credit facility. The bonds issued by Evangeline are non-recourse to Cleco Corporation, and a default on these bonds would not be considered a default under Cleco Corporation’s credit facility. If Cleco Corporation’s credit rating were to be downgraded one level below investment grade, Cleco Corporation would be required to pay fees and interest at a rate of 0.45% higher than the current level for its $150.0 million credit facility. The same downgrade at Cleco Power would require Cleco Power to pay fees and interest at a rate of 0.70% higher than the current level on its $275.0 million credit facility.
 
Cleco Consolidated
Cleco had no short-term debt outstanding at March 31, 2007, or December 31, 2006. At March 31, 2007, and December 31, 2006, Cleco’s long-term debt outstanding was $619.3 million. On March 15, 2007, Cleco repaid $10.0 million of 6.53% medium-term notes at maturity. These medium-term notes were classified as long-term debt due within one year; therefore, the repayment did not affect the total amount of long-term debt recorded. For additional information, see “— Cleco Corporation (Holding Company Level)” and “— Cleco Power” below.
At March 31, 2007, and December 31, 2006, Cleco had a working capital surplus of $65.8 million and $152.6 million, respectively. The $86.8 million decrease in working capital is primarily due to the payment of dividends, additions to
 
 
38
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
property, plant, and equipment, and construction costs for Rodemacher Unit 3.
Cash and cash equivalents available at March 31, 2007, were $98.6 million combined with $407.8 million facility capacity ($132.8 million from Cleco Corporation and $275.0 million from Cleco Power) for total liquidity of $506.4 million. Cash and cash equivalents decreased $93.9 million, when compared to December 31, 2006. This decrease is primarily due to repayment of debt, payment of dividends, an increase in inventory, and additions to property, plant and equipment, including Rodemacher Unit 3. This was partially offset by collection of customer accounts receivables and lower margin deposit requirements.
 
Cleco Corporation (Holding Company Level)
Cleco Corporation had no short-term debt outstanding at March 31, 2007, or December 31, 2006. At March 31, 2007, and December 31, 2006, Cleco Corporation had $100.0 million of long-term debt outstanding related to its 7.00% Senior Notes due May 1, 2008.
Cleco Corporation’s $150.0 million five-year credit facility matures on June 2, 2011. This facility provides for working capital and other needs. Cleco Corporation’s borrowing costs under the facility are equal to LIBOR plus 0.650%, including facility fees.
At March 31, 2007, off-balance sheet commitments reduced available borrowings by an additional $17.2 million, leaving available capacity of $132.8 million. For more information about these commitments, see “— Off-Balance Sheet Commitments.” An uncommitted line of credit with a bank in an amount up to $10.0 million also is available to support Cleco’s working capital needs. This line of credit is available to either Cleco Corporation or Cleco Power.
Cash and cash equivalents available at March 31, 2007, were $93.7 million, combined with $132.8 million facility capacity for total liquidity of $226.5 million. Cash and cash equivalents increased $3.1 million, when compared to December 31, 2006, primarily due to the settlement of affiliate payables and receivables. This was partially offset by the payment of dividends.
 
Cleco Power
There was no short-term debt outstanding at Cleco Power at March 31, 2007, or December 31, 2006. At March 31, 2007, and December 31, 2006, Cleco Power’s long-term debt outstanding was $519.3 million. On March 15, 2007, Cleco Power repaid $10.0 million of 6.53% medium-term notes at maturity. These medium-term notes were classified as long-term debt due within one year; therefore, the repayment did not affect the total amount of long-term debt recorded.
Cleco Power’s $275.0 million five-year credit facility matures on June 2, 2011. This facility provides for working capital and other needs. Cleco Power’s borrowing costs under the facility are equal to LIBOR plus 0.400%, including facility fees.
At March 31, 2007, no amounts were outstanding under Cleco Power’s $275.0 million, five-year facility. 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. This line of credit is available to either Cleco Power or Cleco Corporation.
Cash and cash equivalents available at March 31, 2007, were $4.9 million, combined with $275.0 million facility capacity for total liquidity of $279.9 million. Cash and cash equivalents decreased $97.0 million, when compared to December 31, 2006. This decrease is primarily due to repayment of debt, an increase in inventory, and additions to property, plant and equipment, including Rodemacher Unit 3. This was partially offset by collection of customer accounts receivable and lower margin deposit requirements.
Storm restoration costs from Hurricanes Katrina and Rita are currently estimated to total $158.7 million. During 2006, the LPSC agreed to an interim increase in rates of $23.4 million annually over a ten-year period to recover approximately $161.8 million of estimated storm restoration costs, until a review of the costs by the LPSC was completed. In March 2007, after completing this review, Cleco Power and the LPSC Staff filed a settlement agreement with the LPSC allowing the recovery of essentially all of Cleco Power’s Hurricanes Katrina and Rita storm costs. The agreement also allows Cleco Power to securitize the storm costs and to recover the costs through a customer billing surcharge. Management expects the settlement agreement to be approved by the LPSC in the third quarter of 2007. Cleco Power is also exploring the reimbursement of storm restoration costs from the U.S. Government.
On February 22, 2006, the LPSC approved Cleco Power’s plans to build Rodemacher Unit 3. Terms of the approval included acceptance of an LPSC Staff recommendation that Cleco Power collect from customers an amount equal to 75% of the carrying costs of capital during the construction phase of the unit. In addition to this recovery, Cleco Power plans to fund the construction costs related to Rodemacher Unit 3 by utilizing cash on hand, available funds from its credit facility, the issuance of long-term debt and equity contributions from Cleco Corporation.
The Louisiana State Bond Commission has approved the issuance of up to $200.0 million of tax-exempt bonds to finance the qualifying costs of the solid waste disposal facilities at Rodemacher Unit 3. Thus far, a total of $152.9 million of qualifying costs at Rodemacher Unit 3 has been identified. A total of $60.0 million was allocated by the Governor’s office for issuance in 2006. Cleco Power has applied to the Governor’s office for allocation in 2007 and can apply again in 2008, if necessary, up to the total amount of qualifying costs identified. The $60.0 million of bonds allocated for 2006 were issued on November 21, 2006, by the Rapides Finance Authority, and Cleco Power agreed to pay the debt service on the bonds. The fixed interest rate on the bonds is 4.70%, and the maturity date is November 1, 2036. The bonds may be called at the option of the issuer at the direction of Cleco Power after November 1, 2016.
 
39
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
Midstream
Midstream had no short-term debt outstanding at March 31, 2007, or December 31, 2006.
Evangeline, deconsolidated and no longer reported in Cleco Corporation’s consolidated results, had no short-term debt outstanding at March 31, 2007. Evangeline did have $173.0 million and $177.1 million of long-term debt outstanding at March 31, 2007, and December 31, 2006, respectively, in the form of 8.82% Senior Secured Bonds due 2019. In addition, Evangeline had $7.9 million and $7.6 million of long-term debt due within one year at March 31, 2007, and December 31, 2006, respectively, relating to these bonds. The bonds issued by Evangeline are non-recourse to Cleco Corporation.
 
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, 2007, and December 31, 2006, $36.3 million and $59.0 million of cash, respectively, was restricted. At March 31, 2007, the $36.3 million of restricted cash consisted of $0.1 million under the Diversified Lands mitigation escrow agreement, $25.0 million under the Evangeline senior secured bond indenture, and $11.2 million under the Cleco Power solid waste disposal bonds indenture. Restricted cash at Cleco Power decreased $13.2 million compared to December 31, 2006, due to the release of funds for construction of the solid waste disposal facility at Rodemacher Unit 3. The restricted cash at Evangeline is not included in Cleco Corporation’s Condensed Consolidated Balance Sheets at March 31, 2007, due to the deconsolidation of Evangeline.
 
For information regarding Cleco’s Contractual Obligations and Other Commitments, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — 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, 2006.
 
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 entered into these off-balance sheet commitments in order to entice desired counterparties to contract with its affiliates by providing some measure of credit assurance to the counterparty in the event Cleco’s affiliates do not fulfill certain contractual obligations. If Cleco Corporation had not provided the off-balance sheet commitments, the desired counterparties may not have contracted with Cleco’s affiliates or may have contracted with them at terms less favorable to its affiliates.
The off-balance sheet commitments are not recognized on Cleco’s Condensed Consolidated Balance Sheets, because it has been 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. Some of these commitments reduce borrowings available to Cleco Corporation under its credit facility pursuant to the terms of the credit facility. Cleco’s off-balance sheet commitments as of March 31, 2007, 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, 2007
  
             
REDUCTIONS TO THE
  
             
AMOUNT AVAILABLE
  
             
TO BE DRAWN ON
  
 
FACE
      
NET
 CLECO CORPORATION’S
  
(THOUSANDS)
AMOUNT
  
REDUCTIONS
  
AMOUNT
  
CREDIT FACILITY
  
Cleco Corporation
                
Guarantee issued to Entergy companies for performance obligations of Perryville
$
277,400
  
$
135,000
  
$
142,400
  
$
328
  
Guarantees issued to purchasers of the assets of Cleco Energy
 
1,400
    
-
    
1,400
    
1,400
  
Obligations under standby letter of credit issued to the Evangeline Tolling Agreement
    counterparty
  
15,000
    
-
    
15,000
    
15,000
  
Guarantee issued to Entergy Mississippi on behalf of Attala
  
500
    
-
    
500
    
500
  
Cleco Power
                        
Obligations under standby letter of credit issued to the Louisiana Department of Labor
  
525
    
-
    
525
    
-
  
Obligations under the Lignite Mining Agreement
  
10,920
    
-
    
10,920
    
-
  
Obligations under standby letter of credit issued to the Louisiana Department of Wildlife and
    Fisheries
  
85
    
-
    
85
    
-
  
Total
$
305,830
  
$
135,000
  
$
170,830
  
$
17,228
  
 
Cleco Corporation provided a limited guarantee 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 2005. As of March 31, 2007, the aggregate guarantee of $277.4 million is limited to $142.4 million (other than with respect to the indemnification of environmental matters to which there is no limit) due to the performance of some of the underlying obligations that were guaranteed. The discounted probability-weighted liability under the guarantees and indemnifications as of March 31, 2007, was $0.3 million,
 
 
40
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
resulting in a corresponding reduction in the available credit under Cleco Corporation’s credit facility, which was determined in accordance with the facility’s definition of a contingent obligation. The contingent obligation reduces the amount available under the credit agreement by an amount equal to the reasonably anticipated liability in respect of the contingent obligation as determined in good faith. For additional information on this guarantee, see Note 9 — “Disclosures about Guarantees.”
In November 2004, Cleco completed the sale of substantially all of the assets of Cleco Energy. Cleco Corporation provided guarantees to the buyers of Cleco Energy’s assets for the payment and performance of the indemnity obligations of Cleco Energy. The aggregate amount of the guarantees is $1.4 million, and the guarantees expire in 2009.
If Evangeline fails to perform certain obligations under its tolling agreement, Cleco Corporation will be required to make payments to the Evangeline Tolling Agreement counterparty. Cleco Corporation’s obligation under the Evangeline commitment is in the form of a standby letter of credit from investment grade banks and is limited to $15.0 million. Rating triggers do not exist in the Evangeline Tolling Agreement. Cleco expects Evangeline to be able to meet its obligations under the tolling agreement and does not expect Cleco Corporation to be required to make payments to the counterparty. However, under the covenants associated with Cleco Corporation’s credit facility, the entire net amount of the Evangeline commitment reduces the amount that can be borrowed under the credit facility. The letter of credit for Evangeline is expected to be renewed annually until 2020.
On March 16, 2005, Cleco Corporation issued a guarantee to Central Mississippi Generating Company, LLC for Attala’s obligations and liabilities under the purchase and sale agreement between Central Mississippi Generating Company, LLC and Attala. On January 20, 2007, the guarantee expired. In addition, on January 20, 2006, Cleco Corporation provided a $0.5 million guarantee to Entergy Mississippi for Attala’s obligations under the Interconnection Agreement. This guarantee has no time limit.
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 $0.5 million letter of credit, an amount equal to 110% of the average losses over the previous three years, as surety.
As part of the Lignite Mining Agreement entered into in 2001, 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, 2007, Cleco Power’s 50% exposure for this obligation was approximately $10.9 million. The lignite mining contract is in place until 2011 and does not affect the amount Cleco Corporation can borrow under its credit facility.
On December 1, 2006, Cleco Power issued a standby letter of credit to the Louisiana Department of Wildlife and Fisheries in order to obtain a permit to allow for dredging operations at the Rodemacher Unit 3 site. The letter of credit was for approximately $0.1 million and expired on April 1, 2007.
The following table summarizes the expected termination date of the guarantees and standby letters of credit discussed above:
                   
 
 
 
 
 
 
 
 
AT MARCH 31, 2007
 
 
 
 
 
AMOUNT OF COMMITMENT EXPIRATION PER PERIOD
 
 
 
NET
 
 
 
 
 
 
 
MORE
 
 
 
AMOUNT
 
LESS THAN
 
 
 
 
 
THAN
 
(THOUSANDS)
 
COMMITTED
 
ONE YEAR
 
1-3 YEARS
 
3-5 YEARS
 
5 YEARS
  
Guarantees
  
$
155,220
  
$
-
  
$
1,400
  
$
110,920
  
$
42,900
  
Standby letters of credit
    
15,610
    
610
    
-
    
-
    
15,000
  
Total commercial commitments
  
$
170,830
  
$
610
  
$
1,400
  
$
110,920
  
$
57,900
  
 
 
Wholesale Rates of Cleco
On February 16, 2007, the FERC issued Order No. 890 amending its regulations and the pro forma tariff (a FERC-approved document outlining rates, charges, rules and conditions under which a utility provides wholesale electric service) adopted in FERC Order Nos. 888 and 889 to address apparent deficiencies. The order became effective on March 14, 2007. Cleco Power is in the process of incorporating these new requirements and business practices into its operations.
For additional 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, 2006.
 
Retail Rates of Cleco Power
In March 2007, as a result of Phase II of the LPSC Staff’s review of storm restoration costs, Cleco Power and the LPSC Staff filed a settlement agreement allowing the recovery of essentially all Cleco Power’s Hurricanes Katrina and Rita storm costs, currently estimated to total $158.7 million. Cleco Power is currently recovering these storm costs under an interim rate increase approved by the LPSC. The settlement agreement also allows Cleco Power to securitize the amount of the storm costs and to fund and securitize a $50.0 million reserve for future, extraordinary storm damage costs. Management expects the settlement agreement to be approved by the LPSC in the third quarter of 2007.
 
 
41
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
In April 2006, the LPSC approved a recommendation of the LPSC Staff requiring Cleco Power to refund $1.3 million to customers relating to Cleco Power’s RSP filings for the 12-month periods ended September 30, 2002, 2003, and 2004. Cleco Power refunded the amount as credits on customers’ September 2006 utility bills. However, the LPSC also reserved the right to further review Cleco Power’s calculation of working capital included in the filings for the 12-month periods ended September 30, 2002, 2003, and 2004. Cleco Power reached an agreement of the working capital issue with the LPSC in March 2007 and refunded to customers an additional $3.2 million of previously accrued customer credits in the same month.
In March 2007, the LPSC consultants completed the review of Cleco Power’s RSP monitoring report for the 12-month period ended September 30, 2005. Cleco Power received the LPSC Staff’s report in April 2007 indicating that no refund is due based on the 2005 RSP filing.
For additional information on 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, 2006.
 
Wholesale Electric Markets
On March 16, 2007, to implement the new directives added by Section 215 of the Federal Power Act regarding establishment of reliability standards for all public utilities subject to the FERC’s authority, the FERC issued Order No. 693 approving 83 of the 107 standards currently filed by the North American Electric Reliability Council in its capacity as the authorized ERO. The FERC will begin enforcement of these standards on June 1, 2007. Cleco Power is in the process of incorporating these new reliability standards into its operations.
For additional 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, 2006.
 
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, 2006.
 
Generation RFP
 
2007 Short-Term RFP for 2008 Resources
On January 29, 2007, Cleco Power issued a RFP for a minimum of 50 MW up to 350 MW to meet its 2008 capacity and energy requirements. Proposals were received on February 19, 2007. Cleco Power has selected the winning bids and is currently negotiating with those selected bidders.
 
2007 Long-Term RFP
Cleco Power also plans to release an additional RFP in 2007 to identify long-term resources to fill the needs forecasted by the latest IRP. This RFP will include self-build options that will compete with market bids to provide the most economic and reliable options for Cleco Power customers.

For additional information on Cleco Power’s generation RFPs, 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, 2006.
 
Rodemacher Unit 3
In May 2006, Cleco Power began construction of Rodemacher Unit 3 which will provide a portion of the utility’s future power supply needs. Rodemacher Unit 3 will be capable of burning various solid fuels, but primarily is expected to burn petroleum coke produced by several refineries throughout the Gulf Coast region. All environmental permits for the unit have been received. The total capital cost of the project, including AFUDC, Amended EPC Contract costs, and other development expenses, is estimated at $1.0 billion.
In May 2006, Cleco Power and Shaw entered into the Amended EPC Contract, which provides for substantial completion of construction by the fourth quarter of 2009. The Amended EPC Contract allows for termination at Cleco Power’s sole discretion, which would require payment of escalating termination fees, or if certain milestones, approvals, or other typical commercial terms and conditions are not met. At March 31, 2007, the maximum termination fee would have been $84.7 million. The project remains on schedule for commercial operation no later than the fourth quarter of 2009.
At March 31, 2007, Cleco Power had incurred approximately $309.7 million in project costs.
For additional information on the CCN and construction of Rodemacher Unit 3, please read “Management’s Discussion and Analysis of Financial Condition and Results of Operations — Financial Condition — Liquidity and Capital Resources —Regulatory Matters — Rodemacher Unit 3” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2006. For a discussion of risks associated with the Rodemacher Unit 3 project, see “Risk Factors — Rodemacher Unit 3 Construction Costs,” — “Rodemacher Unit 3 Technical Specifications,” and — “Termination of the Rodemacher Unit 3 Project or the Amended EPC Contract” in the
 
 
42
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2006.
 
Lignite Deferral
For 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, 2006.
In November 2006, Cleco Power and SWEPCO submitted a joint application to the LPSC requesting that Cleco Power recover its existing deferral balance and eliminate any future benchmarking of lignite mining costs. The application was docketed by the LPSC, and Cleco Power and SWEPCO filed testimony in support of the application on January 29, 2007. Cleco Power expects a favorable response to its request, and current and future deferrals are expected to be collected. It is anticipated the LPSC Staff will finalize its review of this information and issue a recommendation during the third quarter of 2007.
If this request is not granted, Cleco Power may be required to expense a portion of the current deferred balance as well as expense future amounts instead of deferring them.
At March 31, 2007, and December 31, 2006, Cleco Power had $21.2 million and $20.1 million, respectively, in deferred costs remaining. Included in the deferred cost balance is interest totaling $3.4 million and $3.0 million as of March 31, 2007, and December 31, 2006, respectively.
For a discussion of risks associated with Cleco Power’s application to recover deferred lignite mining costs, see “Risk Factors — Deferred Lignite Mining Costs” in the Registrants’ Combined Annual Report on Form 10-K for the fiscal year ended December 31, 2006.
 
Franchises
On February 13, 2007, the City Council of Eunice voted to accept a city-wide franchise proposal with a local electric cooperative. The cooperative will now have the opportunity to serve customers city-wide. However, both utilities are required to follow the LPSC 300-foot rule regulation to determine which utility can provide electricity to the customer. In general, if a utility's distribution system is within 300 feet of the new customer's meter point, that utility automatically serves the customer. Otherwise, the customer may choose the electricity provider. This decision does not have a material impact on Cleco Power's results of operations or financial condition, but could reduce future customer and load growth as both utilities compete for new customers.
Historically, Cleco Power has been allowed to recover municipal franchise fees as part of base rates it charges retail customers. Consequently, franchise fees are recovered from customers both inside and outside a franchised area. In October 2006, the LPSC approved the practice of billing franchise fees as a separate line item only to the municipal customers affected, rather than included in base rates to all retail customers. In November 2006, the LPSC placed the order on hold requesting comments from the Louisiana Municipal Association and Louisiana mayors. The LPSC is expected to vote on the implementation of the order in the second quarter of 2007. Cleco Power anticipates no material impact to its results of operations or financial condition if the order is approved.
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, 2006.
 
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.
Congress is considering several bills related to climate change, which may include substantial, mandatory cuts in carbon dioxide and other greenhouse gas emissions. The majority of the bills would require reductions in carbon dioxide from electric generating units. On November 29, 2006, the U.S. Supreme Court heard arguments in a case, Massachusetts vs. E.P.A, in which the U.S. Circuit Court of Appeals for the District of Columbia held that the EPA had discretion to refuse to regulate greenhouse gases from mobile sources. On April 2, 2007, the Supreme Court overturned the lower court’s ruling and found that carbon dioxide and other greenhouse gases are “air pollutants” under the Clean Air Act (CAA). As air pollutants, the Supreme Court’s decision would require the EPA to regulate greenhouse gas emissions from new motor vehicles if, in the EPA’s judgment, such greenhouse gas emissions may reasonably be anticipated to endanger public health or welfare. Based on the Supreme Court’s decision that greenhouse gases are “air pollutants,” the EPA may also decide to use its authority under the CAA to regulate greenhouse gases, such as carbon dioxide, from stationary sources such as power plants. Thus, the Supreme Court ruling could result in federal regulation of carbon dioxide and other greenhouse gas emissions in upcoming years. Cleco will continue to monitor the development of new legislative and regulatory requirements and their potential impacts. While it is unknown at this time what the final outcome of these regulations will entail or whether federal and/or state carbon dioxide laws or regulations will be enacted, any capital and operating costs of
 
43
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
additional pollution control equipment or carbon dioxide emission reduction measures, such as the cost of sequestration or purchasing allowances, or offset credits, that may be required could materially adversely affect future results of operations, cash flows, and possibly financial condition, unless such costs could be recovered through regulated rates and/or future market prices for energy.
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, 2006.
 
Recent Accounting Standards
For a discussion of recent accounting standards, see Item 1, “Notes to the Unaudited Condensed Financial Statements — Note 5 — Recent Accounting Standards” of this 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 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, 2006.
 
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, 2007, and March 31, 2006. The following narrative analysis should be read in combination with Cleco Power’s Unaudited Condensed Financial Statements and the Notes contained in this 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 2007 and the first quarter of 2006. 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, 2006.
For an explanation of material changes in the amount of revenue and expense items of Cleco Power between the first quarter of 2007 and the first quarter of 2006, see “— Results of Operations — Comparison of the Three Months Ended March 31, 2007, and 2006 — Cleco Power” of this 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 is subject to market risk associated with economic hedges relating to open natural gas contracts. Cleco also is subject to market risk associated with its remaining tolling agreement counterparty. For additional information concerning Cleco’s market risk associated with its remaining 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 uses SFAS No. 133 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 of SFAS No. 133, as modified by SFAS No. 149, since Cleco Power generally 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
 
 
44
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
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, corporate-wide aggregate counterparty credit exposure and corporate-wide aggregate counterparty concentration levels. Cleco actively 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.
 
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. 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.
As of March 31, 2007, Cleco had no long-term or short-term variable-rate debt.
 
Commodity Price Risks
Management believes Cleco has controls in place to minimize the risks involved in its financial and energy commodity activities. Independent controls over energy commodity functions consist of a middle office (risk management), a back office (accounting), regulatory compliance staff, as well as oversight by a risk management committee comprised of officers and managers, who are appointed by Cleco’s Board of Directors. VaR limits are established by the Risk Management Committee and monitored through a daily risk report that identifies the current VaR and market conditions.
During 2005, Cleco Power entered into certain financial hedge transactions it considers economic hedges to mitigate the risk associated with fixed-price power to be provided to a wholesale customer through December 2010. These transactions are derivatives as defined by SFAS No. 133 but do not meet the accounting criteria to be considered hedges. These transactions are marked-to-market with the resulting gain or loss recorded on the income statement as a component of operating revenue, net. At March 31, 2007, the positions had a mark-to-market value of $2.4 million, which is an increase of $1.5 million from the mark-to-market value of $0.9 million at December 31, 2006. In addition, these positions resulted in a realized loss of less than $0.1 million for the three months ended March 31, 2007. In light of these economic hedge transactions, volatility in natural gas prices will likely cause fluctuations in the market value of open natural gas positions and ultimately in Cleco Power’s future earnings.
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 fuel costs passed on to customers as encouraged by an LPSC order. In December 2004, Cleco Power implemented a fuel stabilization policy (which was filed with the LPSC and subsequently amended in June 2006) to target higher levels of minimum hedging percentages and mitigate the volatility in customer fuel costs. The change in positions could result in increased volatility in the marked-to-market amounts for the financial positions. These positions are marked-to-market with the resulting gain or loss recorded on the balance sheet as a component of the accumulated deferred fuel asset or liability 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, 2007, the net mark-to-market impact related to open natural gas positions was a loss of $13.2 million. Deferred losses relating to closed natural gas positions at March 31, 2007, totaled $3.5 million.
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, assuming a holding period of one day, with 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 the economic hedge transactions for the three months ended March 31, 2007, as well as the VaR at December 31, 2006, is summarized below:
               
 
 
FOR THE THREE MONTHS
  ENDED MARCH 31, 2007
 
 
AT MARCH 31,
 
 
AT DECEMBER 31,
 
(THOUSANDS)
 
HIGH
 
LOW
 
AVERAGE
 
2007
 
2006
  
Cleco Power
  
$
452.6
  
$
248.0
  
$
358.8
  
$
267.1
  
$
459.5
  
 
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
 
45
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
calculating changes in fair market value and interest expense of its debt obligations.
As of March 31, 2007, Cleco Power had no long-term or short-term variable-rate debt.
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
In accordance with Rules 13a-15 and 15d-15 under the Securities Exchange Act of 1934, the Registrants’ management has evaluated, as of the end of the period covered by this report, with the supervision and participation of the Registrants’ chief executive officer and chief financial officer, the effectiveness of the Registrants’ disclosure controls and procedures as defined by Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934 (Disclosure Controls). Based on that evaluation, such officers concluded that the Registrants’ disclosure controls were effective as of the date of that evaluation.
During the Registrants’ first fiscal quarter of 2007, there have been no changes in the Registrants’ internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Exchange Act) that have materially affected, or are reasonably likely to materially affect, the Registrants’ internal control over financial reporting.

46
 
CLECO CORPORATION
CLECO POWER
2007 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 Financial Statements — Note 8 — Litigation and Other Commitments and Contingencies — Other Litigation,” and Note 15 — “Calpine Bankruptcy.”
 
CLECO POWER
For information on legal proceedings affecting Cleco Power, see Part I, Item 1, “Notes to the Unaudited Condensed Financial Statements — Note 8 — Litigation and Other Commitments and Contingencies — Other Litigation.”
 
ITEM 1A. RISK FACTORS
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 Registrants' Combined Annual Report of Form 10-K for the fiscal year ended December 31, 2006.

 
47
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q
 
 
CLECO CORPORATION
  
10(a)
Executive Employment Agreement between Cleco Corporation and William G. Fontenot effective as of July 28, 2000
 
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, 2007, for Cleco Corporation
 
31(a)
CEO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
CFO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
 
32(a)
CEO and CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
   
 
CLECO POWER
  
10(b)
401(k) Savings and Investment Plan, Stock Trust Agreement, Amendment No. 3, Effective January 1, 2007
 
12(b)
Computation of Ratios of Earnings to Fixed Charges for the three- and twelve-month periods ended March 31, 2007, for Cleco Power
 
31(b)
CEO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
CFO Certification in accordance with section 302 of the Sarbanes-Oxley Act of 2002
 
32(b)
CEO and CFO Certification pursuant to section 906 of the Sarbanes-Oxley Act of 2002
   

 
48
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

SIGNATURE

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 and Chief Accounting Officer




Date: May 2, 2007

 
49
 
CLECO CORPORATION
CLECO POWER
2007 1ST QUARTER FORM 10-Q

SIGNATURE

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 and Chief Accounting Officer




 
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 EX-10.A 2 exhibit10a.htm EXHIBIT 10(A) - EXECUTIVE EMPLOYMENT AGREEMENT BETWEEN CLECO CORPORATION AND WILLIAM G. FONTENOT Exhibit 10(a) - Executive Employment Agreement between Cleco Corporation and William G. Fontenot
Exhibit 10(a)

 
CLECO CORPORATION

EXECUTIVE EMPLOYMENT AGREEMENT
(Level 2 - Form B with a Principal Employer)

THIS AGREEMENT (the “Agreement”) is entered into by and between William G. Fontenot (“Executive”) Cleco Corporation, a corporation organized and existing under the laws of the State of Louisiana (the “Company”), and each of its subsidiaries and affiliates. Cleco Corporation and each of its subsidiaries and affiliates shall act as Executive’s principal employer (the “Principal Employer”). This agreement is intended to amend and restate, with the exception of the term defined therein, that certain Executive Severance Agreement between Cleco Marketing & Trading LLC and Executive, initially effective as of July 28, 2000.

1. EMPLOYMENT AND TERM

1.1 Position. The Principal Employer shall employ and retain Executive as its General Manager - Contracts & Analysis or in such other capacity or capacities as shall be mutually agreed upon, from time to time, by Executive and the Principal Employer (or the Company, as the case may be), and Executive agrees to be so employed, subject to the terms and conditions set forth herein. References herein to the Company shall be deemed to include Executive’s Principal Employer, unless the context clearly indicates to the contrary.

Executive’s duties and responsibilities shall be those assigned to him or her, from time to time, by the Chief Financial Officer of the Company and shall include such duties as are the type and nature normally assigned to similar executive or senior officers of a corporation of the size, type and stature of the Principal Employer. Executive shall report to the Chief Financial Officer of the Company.

1.2 Full Time and Attention. During the term of this Agreement and any extensions or renewals thereof, Executive shall devote his or her full time, attention and energies to the business of the Company and will not, without the prior written consent of the Chief Executive Officer of the Company, be engaged (whether or not during normal business hours) in any other business or professional activity, whether or not such activities are pursued for gain, profit or other pecuniary advantage.

Notwithstanding the foregoing, Executive shall not be prevented from (a) engaging in any civic or charitable activity for which Executive receives no compensation or other pecuniary advantage, (b) investing his or her personal assets in businesses which do not compete with the Company, provided that such investment will not require any services on the part of Executive in the operation of the affairs of the businesses in which investments are made and provided further that Executive’s participation in such businesses is solely that of an investor, or (c) purchasing securities in any corporation whose securities are regularly traded, provided that such purchases will not result in Executive owning beneficially at any time 5% or more of the equity securities of any corporation engaged in a business competitive with that of the Company.
 
 
1.3 Term. Executive’s employment under this Agreement shall commence as of July 28, 2000 (the “Effective Date”), and shall terminate on July 28, 2003 (such date or the last day of employment specified in any renewal or amendment hereof referred to herein as the “Termination Date”) (the period commencing as of the Effective Date and ending as of the Termination Date referred to herein as the “Employment Term”).

Commencing on the second anniversary of the Effective Date and each anniversary thereafter, Executive’s Employment Term shall automatically be extended for an additional one-year period; provided, however, that either party may provide written notice to the other that the Employment Term will not be further extended, such notice to be provided not later than 30 days prior to the end of the then-current Employment Term.

2. COMPENSATION AND BENEFITS

2.1 Base Compensation. The Company shall pay Executive an annual salary equal to his or her annual base salary in effect as of the Effective Date, such amount shall be prorated and paid in equal installments in accordance with the Company’s regular payroll practices and policies and shall be subject to applicable withholding and other applicable taxes (Executive’s “Base Compensation”). Executive’s Base Compensation shall be reviewed no less often than annually and may be increased or reduced by the Chief Executive Officer of the Company, in his sole discretion; provided, however, that Executive’s Base Compensation may not be reduced at any time unless such reduction is part of a reduction in pay uniformly applicable to all similarly situated executives of the Company.

2.2 Annual Incentive Bonus. In addition to the foregoing, Executive shall be eligible for participation in the Annual Incentive Compensation Plan or similar bonus arrangement maintained by the Company or an Affiliate (as defined in Section 6.17) or such other bonus or incentive plans which the Company or its Affiliates may adopt, from time to time, for similarly situated executives (an “Incentive Bonus”). Such participation shall be in accordance with the specific terms and conditions of such plan.

2.3 Long-Term Incentives. In addition to the foregoing, Executive shall be eligible for participation in the 2000 Long-Term Incentive Compensation Plan maintained by the Company and such other long-term incentive plans which the Company or its Affiliates may adopt, from time to time, for similarly situated executives (a “Long-Term Incentive”). Such participation shall be in accordance with the specific terms and conditions of such plan.

2.4 Supplemental Retirement Benefit. In addition to the foregoing, Executive shall be eligible to participate in the Supplemental Executive Retirement Plan maintained by Cleco Utility Group Inc. or such other supplemental retirement benefit plans which the Company or its Affiliates may adopt, from time to time, for similarly situated executives (the “Supplemental Plan”). Such participation shall be in accordance with the specific terms and conditions of such plan.
 
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2.5 Other Benefits. During the term of this Agreement and in addition to the amounts otherwise provided herein, Executive shall participate in such plans, policies, and programs as may be maintained, from time to time, by the Company or its Affiliates for the benefit of similarly situated executives or employees, including, without limitation, profit sharing, life insurance, and group medical and other welfare benefit plans. Any such benefits shall be determined in accordance with the specific terms and conditions of the documents evidencing any such plans, policies, and programs.

2.6 Reimbursement of Expenses. The Company shall reimburse Executive for such reasonable and necessary expenses as are incurred in carrying out his or her duties hereunder, consistent with the Company’s standard policies and annual budget. The Company’s obligation to reimburse Executive hereunder shall be contingent upon the presentment by Executive of an itemized accounting of such expenditures.

3. TERMINATION

3.1 Termination Payments to Executive. As set forth more fully in this Section 3 and except as provided in Section 3.3 and 3.8 hereof, Executive shall be paid the greater of the amounts or benefits set forth below or the amounts or benefits provided under the terms of the separate plan or arrangement maintained by the Company (or its Affiliates) on account of termination of employment hereunder:

 
a.
Executive’s Base Compensation accrued but not yet paid as of the date of his or her termination.

 
b.
An amount equal to 100% of Executive’s Base Compensation, determined at the time of termination, but immediately prior to any reduction in such compensation.

 
c.
An amount equal to Executive’s Incentive Bonus, determined with respect to the year of his or her termination and prorated to reflect Executive’s actual period of service during such year.

 
d.
An amount equal to Executive’s Incentive Bonus, determined as the target amount for the year in which his or her termination of employment occurs.

 
e.
The Company shall, at the written request of Executive:

 
i.
Purchase his or her principal residence if such residence is located within 60 miles of the business location Executive was assigned to prior to termination of employment (the “Principal Residence”) for an amount equal to the greater of (1) the purchase price of such Principal Residence plus the documented cost of any capital improvements to the Principal Residence made by
 
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 Executive, or (2) the fair market value of such Principal Residence as determined by the Company’s usual relocation practice; and
 
 
ii.
Pay or reimburse Executive for the cost of relocating Executive, his or her family and their household goods and other personal property, in accordance with the Company’s usual relocation practice, to any location in the continental United States.

Notwithstanding the foregoing, the Company shall not be obligated hereunder, unless, within 12 months after the termination of his or her employment with the Company (and its Affiliates), the Company is requested to purchase such Principal Residence and Executive has actually relocated from such geographic area.

 
f.
If Executive and/or his or her dependents elects to continue group medical coverage, within the meaning of Code Section 4980B(f)(2), with respect to a group health plan sponsored by the Company or an Affiliate (other than a health flexible spending account under a self-insured medical reimbursement plan described in Code Sections 125 and 105(h)), the Company shall pay the continuation coverage premium for the same type and level of group health plan coverage received by Executive and his or her electing dependents immediately prior to such termination of Executive’s employment for the maximum period provided under Code Section 4980B or until the Executive secures other employment where group health insurance is provided, whichever period is shorter.

Except as expressly provided in Section 3.3 hereof, Executive shall also be entitled to receive such compensation or benefits as may be provided under the terms of a separate plan or agreement maintained by the Company (or its Affiliates) to the extent such compensation or benefits are not duplicative of the compensation or benefits described above.

3.2 Termination for Death or Disability. If Executive dies or becomes disabled during the Employment Term, this Agreement and Executive’s employment hereunder shall immediately terminate and the Company’s obligations hereunder shall automatically cease. In such event, the Company shall pay to Executive (or his or her estate) the compensation described in Sections 3.1a and the additional amount described in Section 3.1c hereof. Payment shall be made in the form of one or more single-sums as soon as practicable after Executive’s death or disability or as and when such amounts are ascertainable.

For purposes of this Section 3.2, Executive shall generally be deemed “disabled” if he or she is actually receiving benefits or is eligible to receive benefits under the Company’s (or an Affiliate’s) separate long-term disability plan or he or she is actually receiving Social Security disability benefits. The Company shall determine whether Executive is disabled hereunder.
 
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3.3 Company’s Termination for Cause. This Agreement and Executive’s employment hereunder may be terminated by the Company on account of Cause. In such event, the Company shall pay to Executive the compensation described in Section 3.1a hereof. Payment shall be made in the form of a single-sum not later than three days after such termination. Notwithstanding any provision of this Agreement or any other plan, policy or agreement evidencing any other compensation arrangement or benefit payable to Executive, no additional amount shall be paid to Executive, except as may be required by law.

For purposes of this Agreement, “Cause” means that Executive has:

 
a.
Committed an intentional act of fraud, embezzlement or theft in the course of his or her employment or otherwise engaged in any intentional misconduct which is materially injurious to the Company’s (or an Affiliate’s) financial condition or business reputation;

 
b.
Committed intentional damage to the property of the Company (or an Affiliate) or committed intentional wrongful disclosure of Confidential Information (as defined in Section 5.2) which is materially injurious to the Company’s (or an Affiliate’s) financial condition or business reputation;

 
c.
Intentionally refused to perform the material duties of his or her position; or

 
d.
A material breach of this Agreement by Executive.

No act or failure to act on the part of Executive will be deemed “intentional” if it was due primarily to an error in judgment or negligence, but will be deemed “intentional” only if done or omitted to be done by Executive not in good faith and without reasonable belief that his or her action or omission was in the best interest of the Company (or an Affiliate).

The Company, acting in good faith, may determine that any termination by the Company is on account of Cause. The Company shall provide written notice to Executive, including a description of the specific reasons for the determination of Cause. Executive shall have the opportunity to present arguments and evidence on his or her behalf to the Chief Executive Officer. Following such presentation (or upon Executive’s failure to appear) the Chief Executive Officer shall confirm that the actions or inactions of Executive constitute Cause hereunder.

3.4 Executive’s Constructive Termination. Executive may terminate this Agreement and his or her employment hereunder on account of a Constructive Termination upon 30 days prior written notice to the Chief Executive Officer (or such shorter period as may be agreed upon by the parties hereto). In such event, the Company shall provide to Executive the compensation described in Section 3.1a hereof, payable not later than three days after his or her termination of employment and the following: (a) the additional amounts determined under Sections 3.1b and 3.1d hereof, payable in not more than two equal installments, one-half not later than 30 days after termination
 
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and the other one-half six months after such termination, and (b) the benefits described in Sections 3.1e and 3.1f hereof.

For purposes of this Agreement, “Constructive Termination” means:

 
a.
A material reduction (other than a reduction in pay uniformly applicable to all similarly situated executives of the Company) in the amount of Executive’s Base Compensation;

 
b.
A material reduction in Executive’s authority, duties or responsibilities from those contemplated in Section 1.1 of this Agreement; or

 
c.
A material breach of this Agreement by the Company or its Affiliates.

No event or condition described in this Section 3.4 shall constitute a Constructive Termination unless (a) Executive promptly gives the Company notice of his or her objection to such event or condition, which notice may be provided orally or in writing to the Chief Executive Officer or his designee, (b) such event or condition is not corrected by the Company promptly after receipt of such notice, but in no event more than 30 days after receipt of notice, and (c) Executive resigns his or her employment with the Company (and all Affiliates) not more than 15 days following the expiration of the 30-day period described in subparagraph (b) hereof.

3.5 Termination by the Company, without Cause. The Company may terminate this Agreement and Executive’s employment hereunder, without Cause, upon 30 days prior written notice to Executive (or such shorter period as may be agreed upon by Executive and the Chief Executive Officer). In such event, the Company shall provide to Executive the compensation described in Section 3.1a hereof, payable not later than three days after such termination, and the following additional amounts and/or benefits: (a) the amounts determined under Sections 3.1b and 3.1d hereof, payable in not more than two equal installments, one-half not later than 30 days after termination and the other one-half six months after such termination, and (b) the benefits described in Sections 3.1e and 3.1f hereof.

3.6 Termination by Executive. Executive may terminate this Agreement and his or her employment hereunder, other than on account of Constructive Termination, upon 30 days prior written notice to the Company or such shorter period as may be agreed upon by the Chief Executive Officer and Executive. In such event, the Company shall pay to Executive the compensation described in Section 3.1a hereof. Payment shall be made in the form of a single-sum not later than three days after such termination. No additional payments or benefits shall be due hereunder, except as may be provided under a separate plan, policy or program evidencing such compensation arrangement or benefit or as may be required by law.

3.7 Return of Property. Upon termination of this Agreement for any reason, Executive shall promptly return to the Company all of the property of the Company (and its Affiliates),
 
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including, without limitation, automobiles, equipment, computers, fax machines, portable telephones, printers, software, credit cards, manuals, customer lists, financial data, letters, notes, notebooks, reports and copies of any of the above and any Confidential Information (as defined in Section 5.2 hereof) that is in the possession or under the control of Executive.

3.8 Consideration for Other Agreements. Executive acknowledges that all or a portion of the amount payable under Section 3.1d hereof is in addition to the amount otherwise due or payable under the Annual Incentive Compensation Plan on account of a separation from service and that the payment of such additional amount is intended to and shall constitute adequate consideration for the execution of such separate waivers or releases as the Company (or its Affiliates) may request Executive to execute in connection with the termination of his or her employment hereunder. Executive agrees that failure to execute any such waiver or release within the time requested by the Company shall result in the forfeiture of the additional amount payable under Section 3.1d hereof.

4. CHANGE IN CONTROL AND BUSINESS TRANSACTION

4.1 Definitions.  The term “Change in Control” and “Business Transaction” shall have the meanings ascribed to them in the Cleco Corporation 2000 Long-Term Incentive Compensation Plan, as the same may be amended from time to time.

The term “Good Reason,” when used herein, shall mean that in connection with a Change in Control:

 
a.
Executive’s Base Compensation in effect immediately before such Change in Control is reduced or there is a significant reduction or termination of Executive’s rights to any employee benefit in effect immediately prior to the Change in Control;

 
b.
Executive’s authority, duties or responsibilities are significantly reduced from those contemplated in Section 1.1 hereof or Executive has reasonably determined that, as a result of a change in circumstances that significantly affects his or her employment with the Company (or an Affiliate), he or she is unable to exercise the authority, power, duties and responsibilities contemplated in Section 1.1 hereof;

 
c.
Executive is required to be away from his or her office in the course of discharging his or her duties and responsibilities under this Agreement significantly more than was required prior to the Change in Control; or

 
d.
Executive is required to transfer to an office or business location located more than 60 miles from the location he or she was assigned to prior to the Change in Control.

No event or condition described in this Section 4.1 shall constitute Good Reason unless (a) Executive gives the Company notice of his or her objection to such event or condition within a reasonable period after Executive learns of such event, which notice may be delivered orally or in
 
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writing to the Chief Executive Officer, (b) such event or condition is not promptly corrected by the Company, but in no event later than 30 days after receipt of such notice, and (c) Executive resigns his or her employment with the Company (and its Affiliates) not more than 60 days following the expiration of the 30-day period described in subparagraph (b) hereof.

4.2 Termination In Connection With a Change in Control. If a Change in Control occurs prior to the expiration of the Employment Term and at any time within the 60-day period preceding or 36-month period following such Change in Control, Executive’s employment described herein is terminated by the Company, without Cause (as defined in Section 3.3 hereof), or Executive terminates his or her employment hereunder for Good Reason, then notwithstanding any provision of this Agreement to the contrary and in lieu of any compensation or benefits otherwise payable hereunder:

 
a.
The Company shall pay to Executive the compensation described in Section 3.1a in the form of a single-sum not later than three days after such termination.

 
b.
The Company shall pay an amount equal to three times Executive’s “base amount,” payable in the form of a single-sum not later than 30 days after such termination. For purposes of this agreement, “base amount” is defined as the Executive’s current annual base compensation and target annual bonus.

 
c.
The Company shall provide the benefits described in Sections 3.1e and 3.1f.

 
d.
Vesting shall be accelerated, any restrictions shall lapse, and all performance objectives shall be deemed satisfied as to any outstanding grants or awards made to Executive under the 2000 Long-Term Incentive Compensation Plan and/or the 1990 Long-Term Incentive Compensation Plan. Executive shall be entitled to such additional benefits or rights as may be provided in the documents evidencing such plans or the terms of any agreement evidencing such grant or award.

 
e.
Executive shall be fully vested for purposes of any service or similar requirement imposed under the Supplemental Plan, regardless of the actual number of years of service attained by Executive; Executive shall be credited with an additional three years of age for purposes of determining his or her benefit percentage under the Supplemental Plan, but in no event shall such benefit percentage be less than 50%; and Executive shall be credited with an additional three years of age for purposes of determining any reduction taken with respect to benefits commencing before Executive’s normal retirement date (as defined in such plan).
 
      4.3 Business Transaction. If Executive’s employment hereunder is terminated (other than on account of Cause as defined in Section 3.3 hereof) in connection with a Business Transaction, then notwithstanding any provision of this Agreement to the contrary, the Company shall pay or provide to Executive benefits as described in Section 4.2.
 
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4.4 Tax Payment. If any payment to Executive pursuant to this Agreement or any other payment or benefit from the Company or an Affiliate in connection with a Change in Control or Business Transaction is subject to the excise tax imposed under Code Section 4999 or any similar excise or penalty tax payable under any United States federal, state, local or other law, the Company shall pay an amount to Executive such that, after the payment by Executive of all taxes on such amount, there remains a balance sufficient to pay such excise or penalty tax. Executive shall submit to the Company the amount to be paid under this Section 4.4, together with supporting documentation. If Executive and the Company disagree as to such amount, an independent public accounting firm agreed upon by Executive and the Company shall make such determination.
 
5. LIMITATIONS ON ACTIVITIES

5.1 Consideration for Limitation on Activities. Executive acknowledges that the execution of this Agreement and the payments described herein constitute consideration for the limitations on activities set forth in this Section 5, the adequacy of which is hereby expressly acknowledged by Executive.

5.2 Confidential Information. Executive recognizes and acknowledges that during the terms of his or her employment, he or she will have access to confidential, proprietary, non-public information concerning the Company and its Affiliates, which may include, without limitation, (a) books and records relating to operations, finance, accounting, personnel and management, (b) price, rate and volume data, future price and rate plans, and test data, (c) information related to product design and development, (d) computer software, customer lists, information obtained on competitors, and sales tactics, and (e) various other non-public trade or business information, including business opportunities, marketing or business diversification plans, methods and processes, and financial data and the like (collectively, the “Confidential Information”). Executive agrees that he or she will not at any time, either while employed by the Company or afterwards, make any independent use of, or disclose to any other person or organization (except as authorized by the Company or pursuant to court order) any of the Confidential Information.

5.3 Non-Solicitation. Executive agrees that during the one-year period commencing as of the date of voluntary termination by Executive (as described in Section 3.6 hereof) or the involuntary termination of Executive on account of Cause (as described in Section 3.3 hereof), he or she shall not, directly or indirectly, for his or her own benefit or on behalf of another or to the Principal Employer’s detriment:

 
a.
Hire or offer to hire any of the Principal Employer’s officers, employees or agents;

 
b.
Persuade or attempt to persuade in any manner any officer, employee or agent of the Principal Employer to discontinue any relationship with the Principal Employer; or
 
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c.
Solicit or divert or attempt to divert any customer or supplier of the Principal Employer.

The provisions of this Section 5.3 shall apply in the locations set forth on Exhibit A hereto, as the same may be amended from time to time. Executive acknowledges that the Principal Employer is presently doing business in such locations and that during the Employment Term Executive will be required to provide services to or for the benefit of the Principal Employer in such locations.

The parties agree that each of the foregoing prohibitions is intended to constitute a separate restriction. Accordingly, should any such prohibition be declared invalid or unenforceable, such prohibition shall be deemed severable from and shall not affect the remainder thereof. The parties further agree that each of the foregoing restrictions is reasonable in both time and geographic scope.

5.4 Business Reputation. Executive agrees that during his or her employment with the Company (and its Affiliates) and at all times thereafter, he or she shall refrain from performing any act, engaging in any conduct or course of action or making or publishing an adverse, untrue or misleading statement which has or may reasonably have the effect of demeaning the name or business reputation of the Company or its Affiliates or which adversely affects (or may reasonably adversely affect) the best interests (economic or otherwise) of the Company or an Affiliate.

5.5 Remedies.  In the event of a breach or threatened breach by Executive of the provisions of Sections 5.2, 5.3 or 5.4 hereof, Executive agrees that the Company shall be entitled to a temporary restraining order or a preliminary injunction (without the necessity of posting bond in connection therewith) and that any additional payments or benefits due to Executive or his or her dependents under Sections 3 and 4 hereof shall be canceled and forfeited. Nothing herein shall be construed as prohibiting the Company from pursuing any other remedy available to it for such breach or threatened breach, including the recovery of damages from Executive.

6. MISCELLANEOUS

6.1 Mitigation Not Required. As a condition of any payment hereunder, Executive shall not be required to mitigate the amount of such payment by seeking other employment or otherwise, nor will any profits, income, earnings or other benefits from any source whatsoever create any mitigation, offset, reduction or any other obligation on the part of Executive under this Agreement.

6.2 Enforcement of this Agreement. In the event any dispute in connection with this Agreement arises with respect to obligations of Executive or the Company that were required prior to the occurrence of a Change in Control or a Business Transaction, all costs, fees and expenses, including attorney fees, of any arbitration or other legal action in connection with such matters in which Executive substantially prevails, shall be borne by, and be the obligation of, the Company.
 
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After a Change in Control or Business Transaction has occurred, Executive shall not be required to incur legal fees and the related expenses associated with the interpretation, enforcement or defense of Executive’s rights under this Agreement by arbitration or otherwise. Accordingly, if, following a Change in Control or Business Transaction, the Company has failed to comply with any of its obligations under this Agreement or the Company or any other person takes or threatens to take any action to declare this Agreement void or unenforceable or in any way reduces the possibility of collecting the amounts due hereunder, or institutes any action or proceeding designed to deny or to recover from Executive the benefits provided or intended to be provided under this Agreement, Executive shall be entitled to retain counsel of Executive’s choice, at the expense of the Company, to advise and represent Executive in connection with any such interpretation, enforcement or defense, including without limitation the initiation or defense of any arbitration or other legal action, whether by or against the Company or any director, officer, stockholder or other person affiliated with the Company, in any jurisdiction. The Company shall pay and be solely financially responsible for any and all attorneys’ and related fees and expenses incurred by Executive in connection with any of the foregoing, without regard to whether Executive prevails, in whole or in part.

In no event shall Executive be required to reimburse the Company for any of the costs and expenses incurred by the Company relating to arbitration or other legal action in connection with this Agreement.
 
6.3 Arbitration. Any dispute, controversy or claim arising out of or relating to this Agreement or Executive’s employment or the termination thereof, including, but not limited to, any claim of discrimination under state or federal law, shall be resolved exclusively by binding arbitration in Alexandria, Louisiana (or such other location as may be agreed to by the parties), in accordance with the rules of the American Arbitration Association then in effect; provided, however, that in the event of a claimed violation of Section 5 hereof, the Company may seek injunctive or other relief specified in Section 5.5 hereof. Judgment may be entered on the arbitrator’s award in any court having competent jurisdiction.

6.4 No Set-Off. There shall be no right of set-off or counterclaim in respect of any claim, debt or obligation against any payment to Executive provided for in this Agreement.

6.5 Assistance with Litigation. For a period of one year after the end of the last period for which Executive will have received any compensation under this Agreement, Executive will furnish such information and proper assistance as may be reasonably necessary in connection with any litigation in which the Company (or an Affiliate) is then or may become involved.

6.6 Headings. Section and other headings contained in this Agreement are for reference purposes only and shall not affect in any way the meaning or interpretation of this Agreement.
 
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6.7 Entire Agreement. This Agreement constitutes the entire understanding and agreement among the parties hereto with respect to the subject matter hereof, and there are no other agreements, understandings, restrictions, representations or warranties among the parties other than those set forth herein.

6.8 Amendments. This Agreement may be amended or modified at any time in any or all respects, but only by an instrument in writing executed by the parties hereto.

6.9 Choice of Law. The validity of this Agreement, the construction of its terms, and the determination of the rights and duties of the parties hereto shall be governed by and construed in accordance with the internal laws of the State of Louisiana applicable to contracts made to be performed wholly within such state.

6.10 Notices. All notices and other communications under this Agreement must be in writing and will be deemed to have been duly given when (a) delivered by hand, (b) sent by telecopier to a telecopier number given below, provided that a copy is sent by a nationally recognized overnight delivery service (receipt requested), or (c) when received by the addressee, if sent by a nationally recognized overnight delivery service (receipt requested), in each case as follows:

 If to Executive:
     William G. Fontenot
      5107 Bluebird Lane
      Alexandria, LA 71303
                   
 If to the Company:
     Cleco Corporation
      2030 Donahue Ferry Road
      Pineville, LA 71360
      Telecopier: 318 484-7777
      Attention: Chief Executive Officer
 
or to such other addresses as a party may designate by notice to the other party.

6.11 Assignment. This Agreement will inure to the benefit of and be binding upon the Company, its Affiliates, successors and assigns, including, without limitation, any person, partnership, company, corporation or other entity that may acquire substantially all of the Company’s assets or business or with or into which the Company may be liquidated, consolidated, merged or otherwise combined, and will inure to the benefit of and be binding upon Executive, his or her heirs, estate, legatees and legal representatives. If payments become payable to Executive’s surviving spouse or other assigns and such person thereafter dies, such payment will revert to Executive’s estate.

6.12 Severability. Each provision of this Agreement is intended to be severable. In the event that any one or more of the provisions contained in this Agreement shall for any reason be
 
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held to be invalid, illegal or unenforceable, the same shall not affect the validity or enforceability of any other provision of this Agreement, but this Agreement shall be construed as if such invalid, illegal or unenforceable provisions was not contained herein. Notwithstanding the foregoing, however, no provision shall be severed if it is clearly apparent under the circumstances that the parties would not have entered into this Agreement without such provision.

6.13 Withholding. The Company (or an Affiliate) may withhold from any payment hereunder any federal, state or local taxes required to be withheld.

6.14 Survival. Notwithstanding anything herein to the contrary, to the extent applicable, the obligations of the Company (and its Affiliates) under Sections 3 and 4, and the obligations of Executive under Sections 3 and 5, shall remain operative and in full force and effect regardless of the expiration of this Agreement.

6.15 Waiver. The failure of either party to insist in any one or more instances upon performance of any terms or conditions of this Agreement will not be construed as a waiver of future performance of any such term, covenant, or condition and the obligations of either party with respect to such term, covenant or condition will continue in full force and effect.

6.16 Delegation. The Chief Executive Officer, in his discretion, may delegate to one or more executive officers of the Company or its Affiliates all or a portion of the power and authority granted to him or the Company hereunder. Such delegation shall be effective whether made orally or in writing.

6.17 Definition. For purposes of this Agreement, “Affiliate” shall mean one or more subsidiaries or other entities with respect to which the Company owns (within the meaning of Section 425(f) of the Internal Revenue Code of 1986, as amended (the “Code”)) 50% or more of the total combined voting power of all classes of stock or other equity interests.

 
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THIS AGREEMENT is executed in multiple counterparts as of the dates set forth below, each of which shall be deemed an original, to be effective as of the Effective Date designated above.
 
CLECO CORPORATION EXECUTIVE
   
By:  /s/ Catherine C. Powell /s/ William G. Fontenot 
    Catherine C. Powell William G. Fontenot
   
Its: Senior V.P., Employee & Corporate Services Date:  6/19/03 
   
Date:  12/17/2002   
   
              
 
THIS AGREEMENT was reviewed and accepted by the Principal Employer, as of the date set forth below, to be effective as of the Effective Date designated above.
 
 
Cleco Corporation
   
By:  /s/ Catherine C. Powell
  
  Its:  Sr. V.P. - Corporate Services 
   
  Date:  6/23/2003 
 
   
 

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CLECO CORPORATION
EXECUTIVE EMPLOYMENT AGREEMENT

EXHIBIT A


This Exhibit A is intended to form a part of that certain Executive Employment Agreement by and between Cleco Corporation, the Principal Employer and William G. Fontenot, first effective as of the Effective Date designated above (the “Agreement”). The parties agree that the proscriptions set forth in Section 5.3 thereof shall apply in the State of Louisiana, Parishes of:

Acadia
Allen
Avoyelles
Beauregard
Calcasieu
Catahoula
DeSoto
Evangeline
Grant
Iberia
Jefferson Davis
Lafayette
Natchitoches
Rapides
Red River
Sabine
St. Landry
St. Martin
St. Mary
St. Tammany
Vernon
Washington

Notwithstanding Section 6.8 of the Agreement, the Principal Employer shall possess the authority to amend this Exhibit A, from time to time, to eliminate parishes in which the Principal Employer is no longer doing business and to add parishes in which the Principal Employer is currently doing business, subject to Executive’s consent, which shall not be unreasonably withheld.
 
15
 
 EX-10.B 3 exhibit10b.htm EXHIBIT 10(B) - 401(K) SAVINGS AND INVESTMENT PLAN, STOCK TRUST AGREEMENT, AMENDMENT NO. 3, EFFECTIVE JANUARY 1, 2007 Exhibit 10(b) - 401(k) Savings and Investment Plan, Stock Trust Agreement, Amendment No. 3, Effective January 1, 2007
 
 
Exhibit 10(b)

 
CLECO POWER LLC
401(k) SAVINGS AND INVESTMENT PLAN
STOCK TRUST AGREEMENT

AMENDMENT NO. 3


WHEREAS, Cleco Power LLC (“Cleco Power” or “Company”) maintains the Cleco Power LLC 401(k) Savings and Investment Plan Stock Trust Agreement in connection with the Cleco Power LLC 401(k) Savings and Investment Plan, as the same has been amended from time to time (the “Plan”), such trust most recently amended and restated effective as of August 1, 1997 (the “Trust Agreement”);

WHEREAS, the Board of Managers of Cleco Power possesses the authority to amend the Trust Agreement, pursuant to Article Thirteenth thereof;

NOW, THEREFORE, effective as of January 1, 2007, the Trust Agreement is amended as follows:


The fifth paragraph of Article Second, entitled “Investment Powers,” is amended and restated in its entirety as follows:

Except (a) in the event of a tender or exchange offer as hereinafter provided, (b) in the case of fractional shares received in any stock dividend, stock split or other recapitalization, (c) as is necessary to make any distribution or payment from the Trust Fund, (d) if the Board of Managers of the Company directs the Trustee to exercise any conversion right, or (e) unless expressly provided by ERISA, the Trustee shall have no power or duty to sell, tender, exchange or otherwise dispose of any of the Company stock held in the Trust Fund (the securities held in such Trust Fund to constitute Company Stock within the meaning of Section 1.10 of the Plan). In the event that a tender or exchange offer is made for all or any portion of the Company Stock held in the Trust Fund, the Trustee shall tender or exchange such shares only on receipt of and in accordance with the directions of the Administrator. All property received in exchange for such Company Stock so tendered shall be held by the Trustee in the Trust Fund subject to the terms and conditions of this Trust Agreement, which agreement shall be deemed amended to permit the holding of such property within such Fund.

THIS AMENDMENT may be executed in multiple counterparts, each of which shall has been deemed an original.
 
 
 
 
  CLECO POWER LLC
   
  By: /s/ G.W. Bausewine
   
 
Its: Sr. Vice President - Corporate Services
   
  Print Name: George W. Bausewine
   
  Date: March 16, 2007
 

REVIEWED AND ACCEPTED by JPMorgan Chase Bank, appointed as the trustee under the Trust Agreement.

 
 
JPMORGAN CHASE BANK
   
  By:  /s/ James K. Bartley
   
 
Its:  Vice President
   
  Print Name:  James K. Bartley
   
 
Date:   April 25, 2007
 


 
2
 EX-12.A 4 exhibit12a.htm EXHIBIT 12(A) - CLECO CORPORATION - COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES AND OF EARNINGS TO COMBINED FIXED CHARGES AND PREFERRED STOCK DIVIDENDS Exhibit 12(a) - Cleco Corporation - Computation of Ratios of Earnings to Fixed Charges and of Earnings to Combined Fixed Charges and Preferred Stock Dividends

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, 2007
  
Earnings from continuing operations
  
$
8,646
  
$
71,092
  
Undistributed equity income from investees
    
1,494
    
5,264
  
Income taxes
    
2,143
    
38,078
  
Earnings from continuing operations before income taxes
  
$
12,283
  
$
114,434
  
Fixed charges:
              
Interest, long-term debt
  
$
10,205
  
$
40,175
  
Interest, other (including interest on short-term debt)
    
2,959
    
7,514
  
Amortization of debt expense, premium, net
    
493
    
1,908
  
Portion of rentals representative of an interest factor
    
131
    
543
  
Total fixed charges
  
$
13,788
  
$
50,140
  
Earnings from continuing operations before income taxes
  
$
12,283
  
$
114,434
  
Plus: total fixed charges from above
    
13,788
    
50,140
  
Plus: amortization of capitalized interest
    
102
    
407
  
Earnings from continuing operations before income taxes and fixed charges
  
$
26,173
  
$
164,981
  
Ratio of earnings to fixed charges
    
1.90
  x  
3.29
  x
Total fixed charges from above
    
13,788
    
50,140
  
Preferred stock dividends
    
528
    
1,944
  
Total fixed charges and preferred stock dividends
    
14,316
    
52,084
  
Ratio of earnings to combined fixed charges and preferred stock dividends
    
1.83
  x  
3.17
  x
 
 EX-12.B 5 exhibit12b.htm EXHIBIT 12(B) - CLECO POWER - COMPUTATION OF RATIOS OF EARNINGS TO FIXED CHARGES Exhibit 12(b) - Cleco Power - Computation of Ratios of Earnings to Fixed Charges

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, 2007
  
Earnings from continuing operations
  
$
12,276
  
$
63,231
  
Income taxes
   
3,116
    
29,118
  
Earnings from continuing operations before income taxes
  
$
15,392
  
$
92,349
  
Fixed charges:
              
Interest, long-term debt
  
$
8,455
  
$
33,175
  
Interest, other (including interest on short-term debt)
    
2,910
    
7,097
  
Amortization of debt expense, premium, net
    
349
    
1,331
  
Portion of rentals representative of an interest factor
    
131
    
543
  
Total fixed charges
  
$
11,845
  
$
42,146
  
Earnings from continuing operations before income taxes
 
$
15,392
  
$
92,349
  
Plus: total fixed charges from above
    
11,845
    
42,146
  
Earnings from continuing operations before income taxes and fixed charges
  
$
27,237
  
$
134,495
  
Ratio of earnings to fixed charges
    
2.30
  x  
3.19
  x

EX-31.A 6 exhibit31a.htm EXHIBIT 31(A) - CLECO CORPORATION - CERTIFICATIONS Exhibit 31(a) - Cleco Corporation - Certifications
 

CLECO CORPORATION
 EXHIBIT 31(a)
 
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 2, 2007
 
 
/s/ Michael H. Madison
Michael H. Madison
     President and Chief Executive Officer

 
 
 
 

CLECO CORPORATION
 EXHIBIT 31(a)
 
Certification
 
I, Kathleen F. Nolen, 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 2, 2007
 
 
/s/ Kathleen F. Nolen
Kathleen F. Nolen
     Senior Vice President, Chief Financial Officer and Treasurer

2
 EX-31.B 7 exhibit31b.htm EXHIBIT 31(B) - CLECO POWER LLC - CERTIFICATIONS Exhibit 31(b) - Cleco Power LLC - Certifications
 
 

CLECO POWER LLC
 EXHIBIT 31(b)

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)) 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) 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

c) 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 2, 2007
 
 
/s/ Michael H. Madison
Michael H. Madison
     Chief Executive Officer

 
 
 
 
 
CLECO POWER LLC
 EXHIBIT 31(b)

Certification
 
I, Kathleen F. Nolen, 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)) 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) 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

c) 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 2, 2007
 
 
/s/ Kathleen F. Nolen
Kathleen F. Nolen
     Senior Vice President, Chief Financial Officer and Treasurer
 
 
2
 EX-32.A 8 exhibit32a.htm EXHIBIT 32(A) - CLECO CORPORATION - CERTIFICATIONS Exhibit 32(a) - Cleco Corporation - Certifications
 
 
CLECO CORPORATION
 EXHIBIT 32(a)

 
 
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, 2007, 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, and I, Kathleen F. Nolen, Senior Vice President, Chief Financial Officer and Treasurer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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


/s/ Michael H. Madison
Michael H. Madison
     President and Chief Executive Officer
 

/s/ Kathleen F. Nolen
Kathleen F. Nolen
     Senior Vice President, Chief Financial Officer and Treasurer

EX-32.B 9 exhibit32b.htm EXHIBIT 32(B) - CLECO POWER LLC - CERTIFICATIONS Exhibit 32(b) - Cleco Power LLC - Certifications
 
CLECO POWER LLC
 EXHIBIT 32(b)

 
 
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, 2007, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), I, Michael H. Madison, Chief Executive Officer of the Company, and I, Kathleen F. Nolen, Senior Vice President, Chief Financial Officer and Treasurer of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, that:

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

/s/ Michael H. Madison
Michael H. Madison
     Chief Executive Officer

 

/s/ Kathleen F. Nolen
Kathleen F. Nolen
     Senior Vice President, Chief Financial Officer and Treasurer
 
 
 10-Q 10 clecocorp10q_may207.pdf CLECO CORPORATION AND CLECO POWER LLC SEC FORM 10-Q FOR THE QUARTERLY PERIOD ENDED MARCH 31, 2007 begin 644 clecocorp10q_may207.pdf M)5!$1BTQ+C0-)>+CS],-"C$W-R`P(&]B:CP\+TA;,3(Y-B`Q,3(T72],:6YE M87)I>F5D(#$O12`T-#0X-B],(#,Q-CDP-2].(#4P+T\@,3@P+U0@,S$S,S$W M/CX-96YD;V)J#2`@("`@("`@("`@("`@#0IX-IB8&!@9F!@36%@8V!@L6408$```:`8&P,+`\<&,)># M`3^8?Y"EF:^08ZO0608&Q@A>'M9#G-K,IJQ+^-]P>?-^%IXA[B?Z'$Q M#RD^\6H1-E$C\1XQ%J%H80'QXV*?A&N$'X@'"ZT162H:(IPBS"'&*)8F>%'$ M3(1;=!5+/--JIE4,_QB^%I8*95R+S)P6F3HM,O"Y7.KQ697'90.?SYMX/*;P MR9Q"E065SR)3)V!UWF&93WO49^4>]^5Q=--Y>$)EI=-^GN*38G*9VV5-#%DE M=H*YSV877G86".R>HOWAN,W$1!CW?JS%\TSOTS8%>Q1;!8Q3N?X8G@<9Y0W2 M^$Q0ILD+57T?4$0OH!MHX(E$%YXK$97+[I0`;5RW%*11!N!3G5MASK5HHA38Z>3'KI&\HW2`3KI-DSES=K_Y_YA&C5=Y^.AST!#=G_^ M7Z<#\JD?LA\+-G4J%+>).)PMWV___25J,`*]N>@I/'PT)K%;`*V[]^?__:7< M[^L_[P::,`])Y0VW`ZA\`JKD#-(0/:,OCN4LY0,I`YD/#;9G@^_-_?\5L M/LY]%A1W>D#30(8`O:,%#^3K4$>"5()]#;/B_^?]=9=CG]Z>QP12"?1@TCF@ MLD3)?*B:#7VR+1XJZ_?^/WB]VYV.H.=W0-TF&A`8.I36,""I/1@H00TY,<&XD)I'W+L@`U!M1WD MY>5`C:7WX%&@#'0_R/!$.9!>4+X`!>PAH+$_P2D!;"G(?&BB2CJ7*`C+<4CI M4[( M(R@H`>6#00-2F0`KTL`2%LBE!395<`E!*)`@6@?$\0VH)1*B`N](8 MX5ZP2E17AB)D75S1"F M"FPV7!%2F'`@62<8&AJ6`5,A&AJ:EI:6`0L0"-!`5HWD%48)>`@80Z("R!8& ML2WH4`J3U@=@!["85!EZ6"^H,02"@=%LP(#`@-C$R(#%LP M(#`@-C$R(#'1=+T5X=$=3=&%T93P\+T=3,2`Q.#(@,"!2/CX^/@UE M;F1O8FH-,3@R(#`@;V)J/#PO5'EP92]%>'1'4W1A=&4O4T$@9F%L7!E+T9O;G1$97-CF5R;R]H>7!H96XO42]P+V$O="]L M+WDO9B]#+U`O=R]P97)I;V0O22]G+VLO<&%R96YL969T+W@O<&%R96YR:6=H M="]U+W8O4B].+U4O4R]!+T(O3"]%+T\O=&AR964O1R]9+TTO8V]M;6$O<75O M=&5D8FQL969T+W%U;W1E9&)L"]S979E;B]E M;61<#6%S:"]E:6=H="]N:6YE+W!E2A(96QV971I M8V$@3%0@4W1D*2]&;VYT4W1R971C:"].;W)M86PO1F]N=%=E:6=H="`S,#`^ M/@UE;F1O8FH-,3@T(#`@;V)J/#PO3&5N9W1H(#4P,S8O1FEL=&5R+T9L871E M1&5C;V1E+U-U8G1Y<&4O5'EP93%#/CYS=')E86T-"DB)=%1I6%-G%K[9;L(6 M()=+AP1NKHA5*`J(@RP6V40LB`9$%@6-280HBP8(,M:V=NRXH-C6J;;.//,X M,X[#J.@4%>H"$F73."PM1FO!C8I*4:MU/#>>.,_= M/6&CG39FUH2-"65GAH?/9!/U%:L,;'9M996AK))=4*ZK,*VK,&FK#/H9;&)I M*9OEO*B2S3)4&DQFY^'_T+'&2E;+5IFT>D.9UK26K5C-QXQZ0^DJ@ZG88&)3 M3-6ZM67:2EV)L=Q0SB;.#V4-&W2EU95&LZ&TEBTUZ@SEE08]6U5BJJ@N+F$S MC.455;7K#/QFE4EKJF7GEZU*"V6UY7JV3%O+\BA-AF(CC]/$)QG+69W!5*7E MUS75)F.EWJBK,E:45\[XQ>+Q=1$0A$1">'@2@;Y$K(!(((@D/Z)$0%001`U! 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