-----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, Q736oqTvgdIudtbryf/76nUZSRuksNTnmpm0qXsN7lwJZCMQx6JoyLYZ4BbfDBPH djrkgof+3EE57WXQE1rZwQ== 0001126956-08-000028.txt : 20080425 0001126956-08-000028.hdr.sgml : 20080425 20080425172508 ACCESSION NUMBER: 0001126956-08-000028 CONFORMED SUBMISSION TYPE: 10-Q PUBLIC DOCUMENT COUNT: 13 CONFORMED PERIOD OF REPORT: 20080331 FILED AS OF DATE: 20080425 DATE AS OF CHANGE: 20080425 FILER: COMPANY DATA: COMPANY CONFORMED NAME: LACLEDE GAS CO CENTRAL INDEX KEY: 0000057183 STANDARD INDUSTRIAL CLASSIFICATION: NATURAL GAS DISTRIBUTION [4924] IRS NUMBER: 430368139 STATE OF INCORPORATION: MO FISCAL YEAR END: 0930 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-01822 FILM NUMBER: 08778698 BUSINESS ADDRESS: STREET 1: 720 OLIVE ST CITY: ST LOUIS STATE: MO ZIP: 63101 BUSINESS PHONE: 3143420500 MAIL ADDRESS: STREET 1: 720 OLIVE ST CITY: ST LOUIS STATE: MO ZIP: 63101 FILER: COMPANY DATA: COMPANY CONFORMED NAME: LACLEDE GROUP INC CENTRAL INDEX KEY: 0001126956 STANDARD INDUSTRIAL CLASSIFICATION: NATURAL GAS DISTRIBUTION [4924] IRS NUMBER: 742976504 STATE OF INCORPORATION: MO FISCAL YEAR END: 0930 FILING VALUES: FORM TYPE: 10-Q SEC ACT: 1934 Act SEC FILE NUMBER: 001-16681 FILM NUMBER: 08778697 BUSINESS ADDRESS: STREET 1: 720 OLIVE ST CITY: ST LOUIS STATE: MO ZIP: 63101 BUSINESS PHONE: 3143420500 MAIL ADDRESS: STREET 1: 720 OLIVE ST STREET 2: RM 1517 CITY: ST LOUIS STATE: MO ZIP: 63101 10-Q 1 form10-qmar2008.htm THE LACLEDE GROUP, INC. MARCH 31, 2008 10-Q form10-qmar2008.htm
 
 
 





 

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 Quarter Ended March 31, 2008
OR
[     ]
TRANSITION REPORT PURSUANT TO SECTION 13 or 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
 
 
Commission File Number
Exact Name of Registrant as Specified in its Charter and Principal Office Address and Telephone Number
 
 
State of Incorporation
I.R.S.
Employer Identification Number
1-16681
The Laclede Group, Inc.
720 Olive Street
St. Louis, MO 63101
314-342-0500
Missouri
74-2976504
1-1822
Laclede Gas Company
720 Olive Street
St. Louis, MO 63101
314-342-0500
Missouri
43-0368139

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 registrant was required to file such report) and (2) have been subject to such filing requirements for the past 90 days.

Yes
[ X ]
No
[     ]

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, or a non-accelerated filer (as defined in Rule 12b-2 of the Exchange Act):
 
The Laclede Group, Inc.:
Large accelerated filer
[     ]
Accelerated filer
[ X ]
Non-accelerated filer
[     ]
             
Laclede Gas Company:
Large accelerated filer
[     ]
Accelerated filer
[     ]
Non-accelerated filer
[ X ]
 
Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act):
                
The Laclede Group, Inc.:
Yes
[     ]
No
[ X ]
         
Laclede Gas Company:
Yes
[     ]
No
[ X ]
 
Indicate the number of shares outstanding of each of the issuer’s classes of common stock as of the latest practicable date:
 
   
Shares Outstanding At
Registrant
Description of Common Stock
April 25, 2008
The Laclede Group, Inc.:
Common Stock ($1.00 Par Value)
21,823,168
Laclede Gas Company:
Common Stock ($1.00 Par Value)
10,365  *
* 100% owned by The Laclede Group, Inc.

 




 
 
 
 



TABLE OF CONTENTS
Page No.
       
PART 1.  FINANCIAL INFORMATION
       
Item 1
Financial Statements
 
       
 
The Laclede Group, Inc.:
 
   
Statements of Consolidated Income
4
   
Statements of Consolidated Comprehensive Income
5
   
Consolidated Balance Sheets
6-7
   
Statements of Consolidated Cash Flows
8
   
Notes to Consolidated Financial Statements
9-22
       
 
Laclede Gas Company:
 
   
Statements of Income
Ex. 99.1, p. 1
   
Statements of Comprehensive Income
Ex. 99.1, p. 2
   
Balance Sheets
Ex. 99.1, p. 3-4
   
Statements of Cash Flows
Ex. 99.1, p. 5
   
Notes to Financial Statements
Ex. 99.1, p. 6-12
       
Item 2
Management’s Discussion and Analysis of Financial Condition and
 
   
Results of Operations (The Laclede Group, Inc.)
23-34
 
Management’s Discussion and Analysis of Financial Condition and
 
   
Results of Operations (Laclede Gas Company)
Ex. 99.1, p. 13-21
       
Item 3
Quantitative and Qualitative Disclosures About Market Risk
35
       
Item 4
Controls and Procedures
35
       
PART II.  OTHER INFORMATION
 
       
Item 1
Legal Proceedings
36
       
Item 2
Unregistered Sales of Equity Securities and Use of Proceeds
36
       
Item 4
Submission of Matters to a Vote of Security Holders
36
       
Item 6
Exhibits
36
       
SIGNATURES – The Laclede Group, Inc.
37
       
SIGNATURES – Laclede Gas Company
38
       
INDEX TO EXHIBITS
39


FILING FORMAT
This Quarterly Report on Form 10-Q is a combined report being filed by two separate registrants: The Laclede Group, Inc. (Laclede Group or the Company) and Laclede Gas Company (Laclede Gas or the Utility).




 
2
 
 


 
PART I. FINANCIAL INFORMATION
   
   
 
The interim financial statements included herein have been prepared by the Company, without audit, pursuant to the rules and regulations of the Securities and Exchange Commission. These financial statements should be read in conjunction with the financial statements and the notes thereto included in the Company’s Form 10-K for the fiscal year ended September 30, 2007.


 



 
3
 
 

Item 1. Financial Statements
THE LACLEDE GROUP, INC.
STATEMENTS OF CONSOLIDATED INCOME
 (UNAUDITED)
 
   
Three Months Ended
     
Six Months Ended
 
   
March 31,
     
March 31,
 
(Thousands, Except Per Share Amounts)
   
2008
   
2007
       
2008
   
2007
 
                               
Operating Revenues:
                             
  Regulated Gas Distribution
 
$
507,089
 
$
493,593
     
$
827,981
 
$
842,081
 
  Non-Regulated Gas Marketing
   
239,387
   
175,850
       
421,185
   
329,317
 
  Other
   
1,230
   
1,257
       
2,530
   
2,434
 
          Total Operating Revenues
   
747,706
   
670,700
       
1,251,696
   
1,173,832
 
Operating Expenses:
                             
  Regulated
                             
      Natural and propane gas
   
377,526
   
373,576
       
600,367
   
625,099
 
      Other operation expenses
   
38,989
   
36,816
       
74,202
   
70,496
 
      Maintenance
   
5,814
   
6,060
       
12,049
   
11,658
 
      Depreciation and amortization
   
8,763
   
8,568
       
17,476
   
17,065
 
      Taxes, other than income taxes
   
29,255
   
28,348
       
45,936
   
47,107
 
          Total Regulated Operating Expenses
   
460,347
   
453,368
       
750,030
   
771,425
 
  Non-Regulated Gas Marketing
   
234,021
   
170,881
       
406,893
   
318,549
 
  Other
   
1,455
   
1,434
       
2,713
   
2,809
 
          Total Operating Expenses
   
695,823
   
625,683
       
1,159,636
   
1,092,783
 
Operating Income
   
51,883
   
45,017
       
92,060
   
81,049
 
Other Income and (Income Deductions) – Net
   
1,076
   
1,074
       
3,725
   
4,376
 
Interest Charges:
                             
  Interest on long-term debt
   
4,875
   
5,625
       
10,001
   
11,251
 
  Interest on long-term debt to unconsolidated affiliate trust
   
70
   
70
       
139
   
139
 
  Other interest charges
   
2,056
   
2,939
       
6,219
   
6,373
 
          Total Interest Charges
   
7,001
   
8,634
       
16,359
   
17,763
 
Income from Continuing Operations Before Income Taxes
                             
   and Dividends on Laclede Gas Redeemable Preferred Stock
   
45,958
   
37,457
       
79,426
   
67,662
 
Income Tax Expense
   
15,889
   
13,437
       
27,811
   
24,222
 
Dividends on Laclede Gas Redeemable Preferred Stock
   
9
   
11
       
19
   
23
 
Income from Continuing Operations
   
30,060
   
24,009
       
51,596
   
43,417
 
Income (Loss) from Discontinued Operations, Net
                             
    of Income Tax (Note 2)
   
21,294
   
(3,190
)
     
20,661
   
(3,511
)
Net Income
 
$
51,354
 
$
20,819
     
$
72,257
 
$
39,906
 
                               
Average Number of Common Shares Outstanding
   
21,589
   
21,445
       
21,571
   
21,413
 
Basic Earnings Per Share of Common Stock:
                             
    Income from Continuing Operations
 
$
1.39
 
$
1.12
     
$
2.39
 
$
2.03
 
    Income (Loss) from Discontinued Operations
   
0.99
   
(0.15
)
     
0.96
   
(0.17
)
    Net Income
 
$
2.38
 
$
0.97
     
$
3.35
 
$
1.86
 
                               
Diluted Earnings Per Share of Common Stock:
                             
    Income from Continuing Operations
 
$
1.39
 
$
1.12
     
$
2.38
 
$
2.02
 
    Income (Loss) from Discontinued Operations
   
0.98
   
(0.15
)
     
0.96
   
(0.16
)
    Net Income
 
$
2.37
 
$
0.97
     
$
3.34
 
$
1.86
 
                               
Dividends Declared Per Share of Common Stock
 
$
0.375
 
$
0.365
     
$
0.750
 
$
0.730
 
                               
See Notes to Consolidated Financial Statements.
                             


 
4
 
 


THE LACLEDE GROUP, INC.
STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME
(UNAUDITED)


   
Three Months Ended
     
Six Months Ended
 
   
March 31,
     
March 31,
 
 (Thousands)
   
2008
   
2007
       
2008
   
2007
 
                               
Net Income
 
$
51,354
 
$
20,819
     
$
72,257
 
$
39,906
 
Other Comprehensive Income (Loss), Before Tax:
                             
  Net gains (losses) on cash flow hedging derivative instruments:
                             
    Net hedging loss arising during period
   
(6,022
)
 
(3,007
)
     
(5,878
)
 
(1,972
    Reclassification adjustment for gains included
                             
      in net income
   
(1,706
)
 
(1,340
)
     
(4,440
)
 
(1,920
    Net unrealized losses on cash flow hedging
                             
      derivative instruments
   
(7,728
)
 
(4,347
)
     
(10,318
)
 
(3,892
  Amortization of actuarial loss included in net periodic
                             
    pension cost
   
43
   
       
86
   
 
Other Comprehensive Loss, Before Tax
   
(7,685
)
 
(4,347
)
     
(10,232
)
 
(3,892
Income Tax Benefit Related to Items of
                             
    Other Comprehensive Income (Loss)
   
(2,969
)
 
(1,680
)
     
(3,953
)
 
(1,504
Other Comprehensive Loss, Net of Tax
   
(4,716
)
 
(2,667
)
     
(6,279
)
 
(2,388
Comprehensive Income
 
$
46,638
 
$
18,152
     
$
65,978
 
$
37,518
 
                               
                               
                               
                               
See Notes to Consolidated Financial Statements.
                             




 









 
5
 
 

THE LACLEDE GROUP, INC.
CONSOLIDATED BALANCE SHEETS
(UNAUDITED)


            
   
March 31,
     
Sept. 30,
     
March 31,
 
(Thousands)
 
2008
     
2007
     
2007
 
                             
ASSETS
                           
Utility Plant
 
$
1,204,984
     
$
1,187,828
     
$
1,165,232
 
Less:  Accumulated depreciation and amortization
   
398,661
       
394,034
       
388,775
 
      Net Utility Plant
   
806,323
       
793,794
       
776,457
 
                             
Non-utility property
   
4,026
       
4,065
       
4,122
 
Other investments
   
44,664
       
43,635
       
42,918
 
Property and investments of discontinued operations
   
       
42,601
       
43,171
 
      Other Property and Investments
   
48,690
       
90,301
       
90,211
 
                             
Current Assets:
                           
  Cash and cash equivalents
   
145,510
       
52,746
       
35,494
 
  Accounts receivable:
                           
      Gas customers – billed and unbilled
   
190,298
       
102,224
       
153,538
 
      Other
   
131,437
       
57,861
       
112,392
 
      Allowances for doubtful accounts
   
(13,749
)
     
(11,232
)
     
(14,237
)
  Delayed customer billings
   
40,417
       
       
36,377
 
  Inventories:
                           
      Natural gas stored underground at LIFO cost
   
31,749
       
138,256
       
43,950
 
      Propane gas at FIFO cost
   
19,904
       
19,950
       
19,951
 
      Materials, supplies, and merchandise at average cost
   
5,409
       
4,990
       
5,900
 
  Derivative instrument assets
   
15,133
       
31,057
       
19,615
 
  Unamortized purchased gas adjustments
   
4,365
       
12,813
       
17,990
 
  Deferred income taxes
   
3,029
       
       
3,781
 
  Prepayments and other
   
5,488
       
27,914
       
14,292
 
  Current assets of discontinued operations
   
       
30,756
       
19,215
 
          Total Current Assets
   
578,990
       
467,335
       
468,258
 
                             
Deferred Charges:
                           
  Prepaid pension cost
   
       
       
58,240
 
  Regulatory assets
   
265,495
       
285,054
       
155,786
 
  Other
   
6,366
       
4,669
       
6,277
 
          Total Deferred Charges
   
271,861
       
289,723
       
220,303
 
Total Assets
 
$
1,705,864
     
$
1,641,153
     
$
1,555,229
 
                             






 
6
 
 



THE LACLEDE GROUP, INC.
CONSOLIDATED BALANCE SHEETS (Continued)
(UNAUDITED)


 
   
March 31,
     
Sept. 30,
     
March 31,
 
(Thousands, except share amounts)
 
2008
     
2007
     
2007
 
                             
CAPITALIZATION AND LIABILITIES
                           
Capitalization:
                           
  Common stock (70,000,000 shares authorized, 21,810,222,
    21,645,637, and 21,571,409 shares issued, respectively)
 
$
21,810
     
$
21,646
     
$
21,571
 
  Paid-in capital
   
139,763
       
136,061
       
132,679
 
  Retained earnings
   
323,581
       
268,761
       
274,674
 
  Accumulated other comprehensive (loss) income
   
(4,422
)
     
1,857
       
1,267
 
      Total Common Stock Equity
   
480,732
       
428,325
       
430,191
 
  Redeemable preferred stock (less current sinking fund
    requirements) – Laclede Gas
   
467
       
627
       
627
 
  Long-term debt to unconsolidated affiliate trust
   
46,400
       
46,400
       
46,400
 
  Long-term debt (less current portion) – Laclede Gas
   
309,152
       
309,122
       
309,082
 
      Total Capitalization
   
836,751
       
784,474
       
786,300
 
                             
Current Liabilities:
                           
  Notes payable
   
171,650
       
211,400
       
117,050
 
  Accounts payable
   
186,944
       
99,109
       
139,312
 
  Advance customer billings
   
       
25,440
       
 
  Current portion of long-term debt and preferred stock
   
160
       
40,160
       
40,160
 
  Wages and compensation accrued
   
11,880
       
11,532
       
11,175
 
  Dividends payable
   
8,303
       
7,970
       
7,962
 
  Customer deposits
   
13,960
       
15,899
       
15,678
 
  Interest accrued
   
10,185
       
11,103
       
10,919
 
  Taxes accrued
   
39,921
       
20,922
       
43,689
 
  Deferred income taxes current
   
       
2,644
       
 
  Other
   
7,419
       
5,756
       
6,596
 
  Current liabilities of discontinued operations
   
       
21,730
       
13,451
 
      Total Current Liabilities
   
450,422
       
473,665
       
405,992
 
                             
Deferred Credits and Other Liabilities:
                           
  Deferred income taxes
   
232,531
       
223,750
       
226,707
 
  Unamortized investment tax credits
   
4,086
       
4,200
       
4,318
 
  Pension and postretirement benefit costs
   
67,515
       
63,678
       
22,182
 
  Asset retirement obligations
   
26,908
       
26,125
       
25,527
 
  Regulatory liabilities
   
64,027
       
39,589
       
58,058
 
  Other
   
23,624
       
22,554
       
22,374
 
  Deferred credits and other liabilities of discontinued operations
   
       
3,118
       
3,771
 
      Total Deferred Credits and Other Liabilities
   
418,691
       
383,014
       
362,937
 
Total Capitalization and Liabilities
 
$
1,705,864
     
$
1,641,153
     
$
1,555,229
 
                             
                             
                             
See Notes to Consolidated Financial Statements.
                           




 
7
 
 


THE LACLEDE GROUP, INC.
STATEMENTS OF CONSOLIDATED CASH FLOWS
(UNAUDITED)
 
   
Six Months Ended
 
   
March 31,
 
(Thousands)
   
2008
     
2007
 
                   
Operating Activities:
                 
  Net Income
 
$
72,257
     
$
39,906
 
  Adjustments to reconcile net income to net cash provided by (used in)
      operating activities:
                 
    Gain on sale of discontinued operations
   
(44,491
)
     
 
    Depreciation, amortization, and accretion
   
18,931
       
19,258
 
    Deferred income taxes and investment tax credits
   
(2,696
)
     
(20,292
)
    Other – net
   
1,410
       
947
 
    Changes in assets and liabilities:
                 
      Accounts receivable – net
   
(159,133
)
     
(118,767
)
      Unamortized purchased gas adjustments
   
8,448
       
26,391
 
      Deferred purchased gas costs
   
53,094
       
64,706
 
      Accounts payable
   
87,835
       
42,384
 
      Delayed customer billings - net
   
(65,857
)
     
(67,820
)
      Taxes accrued
   
18,999
       
28,171
 
      Natural gas stored underground
   
106,507
       
93,526
 
      Other assets and liabilities
   
35,467
       
5,559
 
          Net cash provided by operating activities
   
130,771
       
113,969
 
                   
Investing Activities:
                 
  Proceeds from sale of discontinued operations
   
83,229
       
 
  Capital expenditures
   
(27,744
)
     
(27,216
)
  Other investments
    
26
        
(560
)
          Net cash provided by (used in) investing activities
   
55,511
       
(27,776
)
                   
Financing Activities:
                 
  Maturity of first mortgage bonds
   
(40,000
)
     
 
  Repayment of short-term debt – net
   
(39,750
)
     
(90,250
)
  Issuance of common stock
   
2,439
       
4,311
 
  Dividends paid
   
(16,064
)
     
(15,439
)
  Preferred stock reacquired
   
(160
)
     
(159
)
  Other
    
17
        
60
 
          Net cash used in financing activities
   
(93,518
)
     
(101,477
)
                   
Net Increase (Decrease) in Cash and Cash Equivalents
   
92,764
       
(15,284
)
Cash and Cash Equivalents at Beginning of Period
   
52,746
       
50,778
 
Cash and Cash Equivalents at End of Period
 
$
145,510
     
$
35,494
 
                   
                   
Supplemental Disclosure of Cash Paid During the Period for:
                 
    Interest
 
$
19,662
     
$
18,560
 
    Income taxes
   
22,501
       
9,286
 
                   
                   
See Notes to Consolidated Financial Statements.
                 



 
8
 
 


THE LACLEDE GROUP, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

1.
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

These notes are an integral part of the accompanying consolidated financial statements of The Laclede Group, Inc. (Laclede Group or the Company) and its subsidiaries. In the opinion of Laclede Group, this interim report includes all adjustments (consisting of only normal recurring accruals) necessary for the fair presentation of the results of operations for the periods presented. This Form 10-Q should be read in conjunction with the Notes to Consolidated Financial Statements contained in the Company’s Fiscal Year 2007 Form 10-K.
The consolidated financial position, results of operations, and cash flows of Laclede Group are comprised primarily from the financial position, results of operations, and cash flows of Laclede Gas Company (Laclede Gas or the Utility). Laclede Gas is a regulated natural gas distribution utility having a material seasonal cycle. As a result, these interim statements of income for Laclede Group are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year. Due to the seasonal nature of the business of Laclede Gas, earnings are typically concentrated in the November through April period, which generally corresponds with the heating season.
DISCONTINUED OPERATIONS – On March 31, 2008, Laclede Group sold 100% of its interest in SM&P Utility Resources, Inc. (SM&P), its wholly-owned subsidiary, which comprised the Non-Regulated Services segment. In accordance with generally accepted accounting principles, the results of operations for SM&P are reported as discontinued operations in the statement of income and its associated assets and liabilities are classified separately in the balance sheet. The operating results of SM&P have been aggregated and reported on the Statements of Consolidated Income as Income (Loss) from Discontinued Operations, Net of Income Taxes. The Company has reported in discontinued operations interest expense based on amounts previously recorded by SM&P. Discontinued operations does not include general corporate overheads previously recorded by SM&P. Prior periods have been reclassified to conform to the current-period presentation. For additional information relative to the Company’s sale of SM&P, refer to Note 2, Discontinued Operations.
REVENUE RECOGNITION - Laclede Gas reads meters and bills its customers on monthly cycles. The Utility records its regulated gas distribution revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at March 31, 2008 and 2007, for the Utility, were $31.9 million and $18.5 million, respectively. The amount of accrued unbilled revenue at September 30, 2007 was $11.9 million.
INCOME TAXES - Laclede Group and its subsidiaries have elected, for tax purposes only, various accelerated depreciation provisions of the Internal Revenue Code. In addition, certain other costs are expensed currently for tax purposes while being deferred for book purposes. Effective October 1, 2007, generally accepted accounting principles require that tax benefits be recognized in the financial statements as determined by new recognition and measurement provisions. These provisions permit the benefit from a tax position to be recognized only if, and to the extent that, it is more likely than not that the tax position will be sustained upon examination by the taxing authority, based on the technical merits of the position. Unrecognized tax benefits and related interest and penalties, if any, are recorded as liabilities or as a reduction to deferred tax assets. Laclede Group companies record deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the carrying amounts of assets and liabilities in the financial statements, and the related tax basis. Changes in enacted tax rates, if any, and certain property basis differences will be reflected by entries to regulatory asset or liability accounts for regulated companies, and will be reflected as income or loss for non-regulated companies.
Laclede Gas’ investment tax credits utilized prior to 1986 have been deferred and are being amortized in accordance with regulatory treatment over the useful life of the related property.
GOODWILL - The Company previously reported Goodwill separately on the Consolidated Balance Sheets, the total of which was fully attributable to SM&P, and was included in the Non-Regulated Services operating segment. During the quarter ended March 31, 2008, the Company sold 100% of its interest in SM&P thereby reducing Goodwill to zero at March 31, 2008. Goodwill for prior periods has been reclassified in the Consolidated Balance Sheets and is included in the Property and Investments of Discontinued Operations line. For further information on the sale of SM&P, see Note 2, Discontinued Operations.
GROSS RECEIPTS TAXES - Gross receipts taxes associated with Laclede Gas’ natural gas utility service are imposed on the Utility and billed to its customers. These amounts are recorded gross in the Statements of Consolidated Income. Amounts recorded in Regulated Gas Distribution Operating Revenues for the quarters ended March 31, 2008 and 2007 were $25.2 million and $24.1 million, respectively. Amounts recorded in Regulated Gas Distribution Operating Revenues for the six months ended March 31, 2008 and 2007 were $38.2 million and $38.8 million, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes Other Than Income line.

 
9
 
 


STOCK-BASED COMPENSATION – Awards of stock-based compensation are made pursuant to The Laclede Group 2006 Equity Incentive Plan and the Restricted Stock Plan for Non-Employee Directors. Refer to Note 1 of the Consolidated Financial Statements included in the Company’s Form 10-K for the fiscal year ended September 30, 2007 for descriptions of these plans.
During the six months ended March 31, 2008, the Company awarded 74,100 shares of performance-contingent restricted stock to executive officers at a weighted average grant date fair value of $29.32 per share. This number of shares represents the maximum shares that can be earned pursuant to the terms of the awards. The shares have a performance period ending in September 2010, during which participants are entitled to receive full dividends and voting rights on 49,400 of these shares based on the target level of performance. The number of shares that will ultimately vest is dependent upon the attainment of certain levels of earnings and dividend growth performance goals; further, under the terms of the award, the Compensation Committee (Committee) of the Board of Directors may reduce by up to 50% the number of shares that vest if the Company’s total shareholder return (TSR) during the performance period ranks in the bottom quartile relative to a comparator group of companies. This TSR provision is considered a market condition under generally accepted accounting principles and is discussed further below.
During the six months ended March 31, 2008, the Company made a separate award of 15,000 shares of performance-contingent restricted stock to an executive officer at a weighted average grant date fair value of $33.26 per share. This number of shares represents the maximum shares that can be earned pursuant to the terms of the award. The shares have a performance period ending in September 2009, during which the participant is entitled to receive full dividends and voting rights on 10,000 of these shares based on the target level of performance. The number of shares that will ultimately vest is dependent upon the attainment of certain business development performance metrics and succession management objectives and is not subject to the aforementioned TSR provision.
The weighted average grant date fair value of performance-contingent restricted stock awarded during the six months ended March 31, 2007 was $34.95 per share.
Performance-contingent restricted stock activity for the six months ended March 31, 2008 is presented below:

         
Weighted Average
Grant Date
Fair Value
 
     
Shares
   
                     
 
Nonvested at September 30, 2007
 
110,000
     
$
32.87
   
                     
 
Granted
 
89,100
     
$
29.99
   
 
Vested
 
     
$
   
 
Forfeited
 
(8,000
)
   
$
32.71
   
                     
 
Nonvested at March 31, 2008
 
191,100
     
$
31.53
   
 
During the six months ended March 31, 2008, the Company awarded 23,250 shares of time-vested restricted stock to executives and key employees at a weighted average grant date fair value of $34.25 per share. These shares vest in December 2010. In the interim, participants receive full dividends and voting rights.
During the six months ended March 31, 2008, the Company made a special award of 15,000 time-vested restricted stock units to an executive officer at a weighted average grant date fair value of $28.49 per share. Each restricted stock unit represents a contingent right to receive one share of The Laclede Group common stock. The units vest in December 2011. The participant is required to retain the shares acquired upon vesting for twelve months from the date of delivery of the shares. No dividends are paid or accrue during the vesting period. Furthermore, the participant has no voting rights in the interim.
During the six months ended March 31, 2008, the Company awarded 12,500 shares of time-vested restricted stock to non-employee directors at a weighted average grant date fair value of $33.77 per share. The weighted average fair value of restricted stock awarded to non-employee directors during the six months ended March 31, 2007 was $32.74 per share. These shares vest depending on the participant’s age upon entering the plan and years of service as a director. The plan’s trustee acquires the shares for the awards in the open market and holds the shares as trustee for the benefit of the non-employee directors until the restrictions expire. In the interim, the participants receive full dividends and voting rights.


 
10
 
 

Time-vested restricted stock and time-vested restricted stock unit activity for the six months ended March 31, 2008 is presented below:
 
         
Weighted Average
Grant Date
Fair Value
 
     
Shares/
Units
   
                     
 
Nonvested at September 30, 2007
 
9,000
     
$
32.44
   
                     
 
Granted
 
50,750
     
$
32.43
   
 
Vested
 
(2,900
)
   
$
33.77
   
 
Forfeited
 
     
$
   
                     
 
Nonvested at March 31, 2008
 
56,850
     
$
32.36
   
                     
 
No stock options were granted during the six months ended March 31, 2008. The weighted average fair value of stock options granted during six months ended March 31, 2007 was $8.07 per option.
Stock option activity for the six months ended March 31, 2008 is presented below:

                     
Weighted
         
                     
Average
         
             
Weighted
     
Remaining
     
Aggregate
 
             
Average
     
Contractual
     
Intrinsic
 
             
Exercise
     
Term
     
Value
 
     
Shares
     
Price
     
(Years)
     
($000)
 
                                     
 
Outstanding at September 30, 2007
 
617,100
     
$
30.04
                   
                                     
 
Granted
 
     
$
                   
 
Exercised
 
(31,000
)
   
$
28.67
                   
 
Forfeited
 
(11,875
)
   
$
30.86
                   
 
Expired
 
(7,750
)
   
$
31.14
                   
                                     
 
Outstanding at March 31, 2008
 
566,475
     
$
30.08
     
6.6
     
$
3,144
 
                                     
 
Fully Vested and Expected to Vest
  at March 31, 2008
 
553,612
     
$
30.02
     
6.6
     
$
3,104
 
                                     
 
Exercisable at March 31, 2008
 
382,725
     
$
28.89
     
6.1
     
$
2,580
 
 
The closing price of the Company’s common stock was $35.63 at March 31, 2008.
Compensation cost for performance-contingent restricted stock awards is based upon the probable outcome of the performance conditions. For shares that do not vest or are not expected to vest due to the outcome of the performance conditions, no compensation cost is recognized and any previously recognized compensation cost is reversed.
The fair value of awards of performance-contingent and time-vested restricted stock and restricted stock units, not subject to the TSR provision, is estimated using the closing price of the Company’s stock on the date of the grant. For those awards that do not pay dividends during the vesting period, the estimate of fair value is reduced by the present value of the dividends expected to be paid on the Company’s common stock during the performance period, discounted using an appropriate U.S. Treasury yield. For shares subject to the TSR provision, the estimated impact of this market condition is reflected in the grant date fair value per share of the awards. Accordingly, compensation cost is not reversed to reflect any actual reductions in the awards that may result from the TSR provision. However, if the Company’s TSR during the performance period ranks in the bottom quartile relative to a comparator group of companies and the Committee elects not to reduce the award (or reduce by a lesser amount), this election would be accounted for as a modification of the original award and additional compensation cost would be recognized at that time. The grant date fair value per share of the awards subject to the TSR provision awarded during the six months ended March 31, 2008 was valued by a Monte Carlo simulation model that assessed the probabilities of various TSR outcomes.

 
11
 
 


The amounts of compensation cost recognized for share-based compensation arrangements are presented below:

     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Total compensation cost
 
$
766
 
$
692
 
$
1,422
 
$
1,232
 
 
Compensation cost capitalized
   
(163
)
 
(143
)
 
(298
)
 
(261
)
 
Compensation cost recognized in net income
   
603
   
549
   
1,124
   
971
 
 
Income tax benefit recognized in net income
   
(233
)
 
(212
)
 
(434
)
 
(375
)
 
Compensation cost recognized in net income,
                         
 
  net of income tax
 
$
370
 
$
337
 
$
690
 
$
596
 
 
As of March 31, 2008, there was $5.5 million of total unrecognized compensation cost related to nonvested share-based compensation arrangements (options and restricted stock). That cost is expected to be recognized over a weighted average period of 2.6 years.
NEW ACCOUNTING STANDARDS – In June 2006, the Financial Accounting Standards Board (FASB) issued Interpretation Number 48 (FIN 48), “Accounting for Uncertainty in Income Taxes.” FIN 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with FASB Statement No. 109, “Accounting for Income Taxes.” Under FIN 48, the Company may recognize the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the financial statements from such a position should be measured based on the largest benefit that has a greater than fifty percent likelihood of being realized upon settlement with the taxing authorities. FIN 48 also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition. The Company adopted the provisions of FIN 48 as of October 1, 2007. For details regarding the cumulative effect of adoption and other pertinent information, see Note 6, Income Taxes.
In September 2006, the FASB issued Statement of Financial Accounting Standards (SFAS) No. 157, “Fair Value Measurements.” This Statement defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles, and expands disclosures about fair value measurements. The Statement applies to fair value measurements required under other accounting guidance that require or permit fair value measurements. Accordingly, this Statement does not require any new fair value measurements. The guidance in this Statement does not apply to the Company’s stock-based compensation plans accounted for in accordance with SFAS No. 123(R), “Share-Based Payment.” Except as described below, SFAS No. 157 is effective for the Company as of the beginning of fiscal year 2009. In February 2008, the FASB issued two Staff Positions that amend SFAS No. 157. The first FASB Staff Position (FSP), No. FAS 157-1, excludes from the scope of SFAS No. 157 accounting pronouncements that address fair value measurements for purposes of lease classification and measurement. The second FSP, No. FAS 157-2, delays the effective date of SFAS No. 157 for nonfinancial assets and nonfinancial liabilities, except for items that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually). Application of SFAS No. 157 to these items will be effective for the Company as of the beginning of fiscal year 2010. The Company is currently evaluating the potential impact of this Statement, as amended by these Staff Positions, on its consolidated financial statements.
In September 2006, the FASB issued SFAS No. 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans.” As discussed in Note 2 to the Consolidated Financial Statements included in the Company’s Fiscal Year 2007 Form 10-K, Laclede Group adopted the recognition and disclosure provisions of this Statement effective September 30, 2007. The Statement also requires that plan assets and benefit obligations be measured as of the date of the employer’s fiscal year-end statement of financial position. This requirement is effective for the Company as of the end of fiscal year 2009. In conjunction with adoption of this provision of SFAS No. 158, the Company will be required to change its valuation date for its pension and other postretirement plans from June 30 to September 30. The Company is currently evaluating the impact of adoption of the change in measurement date on its consolidated financial statements.
In February 2007, the FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities.” The Statement permits entities to choose to measure many financial instruments and certain other items at fair value that are not currently required to be measured at fair value. SFAS No. 159 also establishes presentation and disclosure requirements designed to facilitate comparisons between entities that choose different measurement attributes for similar types of assets and liabilities. This Statement does not affect any existing accounting literature that requires certain assets and liabilities to be carried at fair value. Upon adoption of SFAS No. 159, entities are permitted to choose, at specified election dates, to measure eligible items at fair value (fair value option). Unrealized gains and losses on items for which the fair value option has been elected are reported in earnings at each reporting date. The decision about

 
12
 
 

whether to elect the fair value option is applied instrument by instrument with few exceptions. The decision is also irrevocable (unless a new election date occurs) and must be applied to entire instruments and not to portions of instruments. SFAS No. 159 requires that cash flows related to items measured at fair value be classified in the statement of cash flows according to their nature and purpose as required by SFAS No. 95, “Statement of Cash Flows” (as amended). SFAS No. 159 is effective for the Company as of the beginning of fiscal year 2009. The Company is currently evaluating the provisions of this Statement.
In June 2007, the FASB ratified the consensus reached in Emerging Issues Task Force (EITF) Issue No. 06-11, “Accounting for Income Tax Benefits of Dividends on Share-Based Payment Awards.” This Issue addresses how an entity should recognize the tax benefit received on dividends that are (a) paid to employees holding equity-classified nonvested shares, equity-classified nonvested share units, or equity-classified outstanding share options and (b) charged to retained earnings under SFAS No. 123(R). The Task Force reached a consensus that such tax benefits should be recognized as an increase in additional paid-in capital. This EITF Issue also addresses how the accounting for these tax benefits is affected if an entity’s estimate of forfeitures changes in subsequent periods. This EITF Issue is effective for Laclede Group as of the beginning of fiscal year 2009. The Company is currently evaluating the provisions of this EITF Issue.
In December 2007, the FASB issued SFAS No. 160, “Noncontrolling Interests in Consolidated Financial Statements.” This Statement amends Accounting Research Bulletin No. 51, “Consolidated Financial Statements.” A noncontrolling interest, sometimes called a minority interest, is the portion of equity in a subsidiary not attributable, directly or indirectly, to a parent. SFAS No. 160 clarifies that noncontrolling interests should be separately reported as equity in the balance sheet. Additionally, SFAS No. 160 requires certain changes in presentation to income statements. SFAS No. 160 also addresses accounting for changes in the parent’s ownership interest of a subsidiary, accounting for the deconsolidation of a subsidiary, and disclosure requirements. This Statement is effective for Laclede Group as of the beginning of fiscal year 2010. Currently, all of Laclede Group’s consolidated subsidiaries are wholly owned and therefore adoption of this Statement is not expected to have any effect on the Company’s consolidated financial statements.
In December 2007, the FASB issued SFAS No. 141 (revised 2007) (141(R)), “Business Combinations.” This Statement revises SFAS No. 141 but retains the fundamental requirements in SFAS No. 141 that the acquisition method (formerly known as purchase method) of accounting be used for all business combinations. SFAS No. 141(R) requires an acquirer to recognize the assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at the acquisition date, measured at their fair values as of that date, with limited exceptions specified in the Statement. SFAS 141(R) requires acquisition-related costs to be accounted for separately instead of being allocated to the assets acquired and liabilities assumed. SFAS No. 141(R) also amends the guidance related to the recognition of certain assets acquired and liabilities assumed that relate to contingencies, research and development assets acquired that have no alternative future use, and negative goodwill arising from a bargain purchase. Laclede Group is required to adopt SFAS No. 141(R) prospectively to business combinations with acquisition dates on or after October 1, 2009 (fiscal 2010). Because this Statement is only applicable to future business combinations, existing amounts reported on the Company’s consolidated financial statements will not be impacted by adoption of this Statement.
In March 2008, the FASB issued SFAS No. 161, “Disclosures about Derivative Instruments and Hedging Activities.” This Statement amends SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities,” by requiring enhanced disclosures about (a) how and why an entity uses derivative instruments, (b) how derivative instruments and related hedged items are accounted for under Statement 133 and its related interpretations, and (c) how derivative instruments and related hedged items affect an entity’s financial position, financial performance, and cash flows. This Statement will be effective for the Company’s interim and annual financial statements beginning in fiscal year 2010. This Statement encourages, but does not require, comparative disclosures for earlier periods at initial adoption. The Company is currently evaluating the provisions of this Statement.


2.
DISCONTINUED OPERATIONS

On March 31, 2008, the Company completed the sale of 100% of its interest in its wholly-owned subsidiary, SM&P, to Stripe Acquisition, Inc. (an affiliate of Kohlberg Management VI, LLC) for $85 million in cash, subject to certain closing and post-closing adjustments. SM&P is an underground facilities locating and marking business that comprised Laclede Group’s Non-Regulated Services operating segment. The sales agreement included representations, warranties, and indemnification provisions customary for such transactions and is filed as an exhibit to this Form 10-Q. For information concerning Laclede Group’s obligations under these provisions, see Note 9, Commitments and Contingencies.

 
13
 
 


In accordance with generally accepted accounting principles, the operating results of SM&P have been aggregated and reported on the Statements of Consolidated Income as Income (Loss) from Discontinued Operations, Net of Income Tax. The Company has reported in discontinued operations interest expense based on amounts previously recorded by SM&P. For the quarters ended March 31, 2008 and 2007, discontinued operations includes pre-tax interest expense of $0.8 million. For the six months ended March 31, 2008 and 2007, discontinued operations includes pre-tax interest expense of $1.6 million. Discontinued operations does not include general corporate overheads. Income (Loss) from Discontinued Operations reported in the Statements of Consolidated Income consists of the following:

     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Operating revenues
 
$
28,062
 
$
30,134
 
$
65,423
 
$
66,563
 
                             
 
Loss from operations
   
(8,433
)
 
(5,107
)
 
(9,387
)
 
(5,564
)
 
Gain on disposal
   
44,491
   
   
44,491
   
 
 
Pre-tax income (loss)
   
36,058
   
(5,107
)
 
35,104
   
(5,564
)
 
Income tax expense (benefit)
   
14,764
   
(1,917
)
 
14,443
   
(2,053
)
 
Income (Loss) From Discontinued Operations
 
$
21,294
 
$
(3,190
)
$
20,661
 
$
(3,511
)
 
The assets and liabilities of SM&P have been segregated from continuing operations and have been reported as assets or liabilities of discontinued operations on the Consolidated Balance Sheets. Assets and liabilities of SM&P reported in the Consolidated Balance Sheets as discontinued operations consist of the following:

     
Sept. 30,
 
March 31,
 
 
(Thousands)
 
2007
 
2007
 
                 
 
Assets
             
 
  Property and Investments:
             
 
    Goodwill
 
$
33,595
 
$
33,595
 
 
    Property, plant, and equipment – net
   
7,204
   
7,941
 
 
    Other investments
   
1,802
   
1,635
 
 
          Total Property and Investments
   
42,601
   
43,171
 
 
  Current Assets:
             
 
    Accounts receivable – net
   
28,816
   
18,246
 
 
    Other
   
1,940
   
969
 
 
          Total Current Assets
   
30,756
   
19,215
 
 
Total Assets
 
$
73,357
 
$
62,386
 
                 
 
Liabilities
             
 
  Current Liabilities:
             
 
    Accounts payable
 
$
7,720
 
$
4,487
 
 
    Wages and compensation accrued
   
3,950
   
3,672
 
 
    Other
   
10,060
   
5,292
 
 
          Total Current Liabilities
   
21,730
   
13,451
 
 
  Deferred credits and other liabilities
   
3,118
   
3,771
 
 
Total Liabilities
 
$
24,848
 
$
17,222
 

 
14
 
 


3.
EARNINGS PER SHARE

SFAS No. 128, “Earnings Per Share,” requires dual presentation of basic and diluted earnings per share (EPS). Basic EPS does not include potentially dilutive securities and is computed by dividing net income by the weighted average number of common shares outstanding during the period. Diluted EPS assumes the issuance of common shares pursuant to the Company’s stock-based compensation plans at the beginning of each respective period, or at the date of grant or award, if later. Shares attributable to stock options and time-vested restricted stock are excluded from the calculation of diluted earnings per share if the effect would be antidilutive. For both the quarter and six months ended March 31, 2008, 105,500 shares attributable to antidilutive outstanding stock options were excluded from the calculation of diluted earnings per share. For the quarter and six months ended March 31, 2007, there were 209,500 and 115,500 antidilutive shares, respectively. Performance-contingent restricted stock awards are only included in the calculation of diluted earnings per share to the extent the underlying performance conditions are satisfied (a) prior to the end of the reporting period or (b) would be satisfied if the end of the reporting period were the end of the related contingency period and the result would be dilutive. For both the quarter and six months ended March 31, 2008, 158,200 shares of nonvested performance-contingent restricted stock were excluded from the calculation of diluted earnings per share. For both the quarter and six months ended March 31, 2007, 110,000 shares were excluded.

             
Three Months Ended
     
Six Months Ended
 
             
March 31,
     
March 31,
 
 
(Thousands, Except Per Share Amounts)
           
2008
   
2007
       
2008
   
2007
 
                                         
 
Basic EPS:
                                     
 
Income from Continuing Operations
         
$
30,060
 
$
24,009
     
$
51,596
 
$
43,417
 
                                         
 
Weighted Average Shares Outstanding
           
21,589
   
21,445
       
21,571
   
21,413
 
 
Earnings Per Share of Common Stock from
                                     
 
  Continuing Operations
         
$
1.39
 
$
1.12
       
2.39
 
$
2.03
 
                                         
 
Diluted EPS:
                                     
 
Income from Continuing Operations
         
$
30,060
 
$
24,009
     
$
51,596
 
$
43,417
 
                                         
 
Weighted Average Shares Outstanding
           
21,589
   
21,445
       
21,571
   
21,413
 
 
Dilutive Effect of Stock Options
                                     
 
and Restricted Stock
           
96
   
43
       
82
   
52
 
 
Weighted Average Diluted Shares
           
21,685
   
21,488
       
21,653
   
21,465
 
                                         
 
Earnings Per Share of Common Stock from
                                     
 
  Continuing Operations
         
$
1.39
 
$
1.12
     
$
2.38
 
$
2.02
 

4.
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

Laclede Gas has non-contributory defined benefit, trusteed forms of pension plans covering substantially all employees over the age of twenty-one. Benefits are based on years of service and the participant’s compensation during the highest three years of the last ten years of employment. Plan assets consist primarily of corporate and U.S. government obligations and pooled equity funds.
Pension costs for the quarters ending March 31, 2008 and 2007 were $1.5 million and $1.4 million, respectively, including amounts charged to construction. Pension costs for the six months ended March 31, 2008 and 2007 were $3.1 million and $2.7 million, respectively, including amounts charged to construction.
The net periodic pension costs include the following components:

 
15
 
 



     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Service cost – benefits earned
                         
 
during the period
 
$
3,243
 
$
3,105
 
$
6,485
 
$
6,211
 
 
Interest cost on projected
                         
 
benefit obligation
   
4,670
   
4,483
   
9,340
   
8,965
 
 
Expected return on plan assets
   
(5,163
)
 
(5,074
)
 
(10,325
)
 
(10,148
)
 
Amortization of prior service cost
   
272
   
283
   
544
   
567
 
 
Amortization of actuarial loss
   
791
   
921
   
1,582
   
1,841
 
 
Sub-total
   
3,813
   
3,718
   
7,626
   
7,436
 
 
Loss on lump sum settlement
   
   
945
   
   
945
 
 
Regulatory adjustment
   
(2,280
)
 
(3,309
)
 
(4,560
)
 
(5,673
)
 
Net pension cost
 
$
1,533
 
$
1,354
 
$
3,066
 
$
2,708
 
 
Pursuant to the provisions of the Laclede Gas pension plans, pension obligations may be satisfied by lump-sum cash payments. Pursuant to a Missouri Public Service Commission (MoPSC or Commission) Order, lump-sum payments are recognized as settlements (which can result in gains or losses) only if the total of such payments exceeds 100% of the sum of service and interest costs. No lump sum payments were recognized as settlements during the six months ended March 31, 2008. Lump sum payments recognized as settlements during the six months ended March 31, 2007 were $2.8 million.
Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains or losses not yet includible in pension cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for the Utility’s qualified pension plans is based on an allowance of $4.1 million annually effective October 1, 2005 and $4.8 million annually effective August 1, 2007. The difference between this amount and pension expense as calculated pursuant to the above and that otherwise would be included in the Statements of Consolidated Income and Consolidated Comprehensive Income is deferred as a regulatory asset or regulatory liability.
SM&P maintains a non-qualified, defined benefit plan with four participants that was frozen to new participants in 2002. The plan is a non-qualified plan and therefore has no assets held in trust. Net pension cost related to the plan is not material. The Company sold 100% of its interest in SM&P on March 31, 2008, and the liabilities for this plan remain with SM&P.
Laclede Gas provides certain life insurance benefits at retirement. Medical insurance is available after early retirement until age 65. The transition obligation not yet includible in postretirement benefit cost is being amortized over 20 years. Postretirement benefit costs for the quarters ended March 31, 2008 and 2007 were $1.9 million and $2.0 million, respectively, including amounts charged to construction. Postretirement benefit costs for the six months ended March 31, 2008 and 2007 were $3.8 million and $3.9 million, respectively, including amounts charged to construction.
Net periodic postretirement benefit costs consisted of the following components:

     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Service cost – benefits earned
                         
 
during the period
 
$
1,140
 
$
1,015
 
$
2,280
 
$
2,031
 
 
Interest cost on accumulated
                         
 
postretirement benefit obligation
   
977
   
900
   
1,954
   
1,800
 
 
Expected return on plan assets
   
(509
)
 
(431
)
 
(1,019
)
 
(862
)
 
Amortization of transition obligation
   
34
   
34
   
68
   
68
 
 
Amortization of prior service cost
   
(582
)
 
(582
)
 
(1,164
)
 
(1,164
)
 
Amortization of actuarial loss
   
746
   
812
   
1,492
   
1,623
 
 
Sub-total
   
1,806
   
1,748
   
3,611
   
3,496
 
 
Regulatory adjustment
   
105
   
223
   
210
   
446
 
 
Net postretirement benefit cost
 
$
1,911
 
$
1,971
 
$
3,821
 
$
3,942
 



 
16
 
 


Missouri state law provides for the recovery in rates of SFAS No. 106, “Employers’ Accounting for Postretirement Benefits Other Than Pensions,” accrued costs provided that such costs are funded through an independent, external funding mechanism. Laclede Gas established Voluntary Employees’ Beneficiary Association (VEBA) and Rabbi trusts as its external funding mechanisms. VEBA and Rabbi trusts’ assets consist primarily of money market securities and mutual funds invested in stocks and bonds.
Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains and losses not yet includible in postretirement benefit cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the accumulated postretirement benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. Previously, the recovery in rates for the postretirement benefit costs was based on an alternative methodology for amortization of unrecognized gains and losses as ordered by the MoPSC. The Commission ordered that the recovery in rates be based on an annual allowance of $7.6 million, effective August 1, 2007. The difference between this amount and postretirement benefit cost based on the above and that otherwise would be included in the Statements of Consolidated Income and Consolidated Comprehensive Income is deferred as a regulatory asset or regulatory liability.


5.
FINANCIAL INSTRUMENTS

In the course of its business, Laclede Group’s non-regulated gas marketing affiliate, Laclede Energy Resources, Inc. (LER), enters into fixed-price commitments associated with the purchase or sale of natural gas. LER manages the price risk associated with these commitments by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of exchange-traded futures contracts to lock in margins. At March 31, 2008, LER’s unmatched positions were not material to Laclede Group’s financial position or results of operations.

Settled and open futures positions were as follows at March 31, 2008:

     
 
 
Position Month
 
 
MMBtu
(millions)
 
Average
Price per
MMBtu
 
 
Settled short positions
 
April 2008
 
2.63
 
$
8.66
 
 
Settled long positions
 
April 2008
 
.01
   
9.67
 
                   
 
Open short futures positions
 
May 2008
 
.17
   
8.19
 
     
June 2008
 
.15
   
8.96
 
     
July 2008
 
.15
   
9.04
 
     
August 2008
 
.15
   
9.08
 
     
September 2008
 
.45
   
9.40
 
     
October 2008
 
.15
   
9.17
 
     
November 2008
 
.58
   
9.78
 
     
December 2008
 
.34
   
9.55
 
     
January 2009
 
.31
   
9.76
 
     
February 2009
 
.31
   
9.74
 
     
March 2009
 
.27
   
9.69
 
     
November 2009
 
.10
   
8.80
 
     
December 2009
 
.15
   
8.83
 
     
January 2010
 
.15
   
8.83
 
     
February 2010
 
.15
   
8.83
 
     
March 2010
 
.10
   
8.80
 
                   
 
Open long futures positions
 
May 2008
 
.06
   
7.60
 
     
June 2008
 
.06
   
7.60
 
     
July 2008
 
.06
   
7.60
 
     
August 2008
 
.06
   
7.60
 
     
September 2008
 
.06
   
7.60
 
     
October 2008
 
.06
   
7.60
 
     
November 2008
 
.06
   
7.60
 
     
December 2008
 
.06
   
7.60
 
     
April 2009
 
.30
   
8.94
 


 
17
 
 


The above futures contracts are derivative instruments, and management has designated these items as cash flow hedges of forecasted transactions. The fair values of the instruments are recognized on the Consolidated Balance Sheets. The change in the fair value of the effective portion of these hedge instruments is recorded, net of tax, in Other Comprehensive Income. Accumulated Other Comprehensive Income is a component of Total Common Stock Equity. These amounts will reduce or be charged to Non-Regulated Gas Marketing Operating Revenues or Expenses in the Statements of Consolidated Income as the hedged transactions occur. As of March 31, 2008, it is expected that approximately $4.2 million of pre-tax unrealized losses will be reclassified into the Consolidated Statement of Income during the next twelve months. The ineffective portions of these hedge instruments are charged or credited to Non-Regulated Gas Marketing Operating Revenues or Expenses. The net amount of pre-tax losses recognized in earnings for the ineffective portion of cash flow hedges was $0.6 million for the quarter ended March 31, 2008 and $0.3 million for the six months ended March 31, 2008. The amount of pre-tax losses recognized in earnings for the ineffective portion of cash flow hedges was $1.0 million for the quarter ended March 31, 2007 and $0.5 million for the six months ended March 31, 2007. Cash flows from hedging transactions are classified in the same category as the cash flows from the items that are being hedged in the Statements of Consolidated Cash Flows.


6.
INCOME TAXES

The Company adopted the provisions of FIN 48, “Accounting for the Uncertainty in Income Taxes,” as of October 1, 2007. FIN 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with FASB Statement No. 109, “Accounting for Income Taxes.” Pursuant to FIN 48, the Company may recognize the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position.
Upon adoption of FIN 48, the Company recognized a reduction to beginning retained earnings for a cumulative-effect adjustment totaling $1.1 million, reclassified $2.5 million of income tax liabilities from current to non-current liabilities, and increased its liabilities for accrued interest and penalties. Total unrecognized tax benefits as of October 1, 2007 were $2.1 million, all of which would favorably impact the effective tax rate, if recognized. The Company recognizes potential accrued interest and penalties related to its uncertain tax positions as interest expense and other income deductions, respectively. Potential interest and penalties accrued (net of income tax benefit) associated with the Company’s uncertain tax positions were $1.5 million at October 1, 2007. Unrecognized tax benefits, accrued interest payable, and accrued penalties payable are included in the Other line of the Deferred Credits and Other Liabilities section of the Consolidated Balance Sheets.
The Company is subject to U.S. federal income tax as well as income tax of state and city jurisdictions. The Company is no longer subject to examination for fiscal years prior to 2004. The statute of limitations remains open until June 15, 2009 and 2010 for fiscal years 2005 and 2006, respectively. However, during the quarter ended March 31, 2008, the Company effectively settled an audit with the Internal Revenue Service for those periods. Completion of the audit represents an event requiring the Company to re-evaluate its uncertain tax positions. As a result, the Company recognized fiscal years 2005 and 2006 unrecognized tax benefits of $1.0 million, which favorably impacted the effective tax rate, and reversed $1.6 million of accrued interest and penalties (net of income tax benefit). The Company currently expects to recognize $0.4 million of tax benefits, including the reversal of accrued interest and penalties, in June 2008 due to the expiration of the statute of limitations for fiscal year 2004.
Total FIN 48 unrecognized tax benefits at March 31, 2008 were $1.1 million, all of which would favorably impact the effective tax rate, if recognized. Potential interest and penalties associated with these liabilities were $0.1 million. The Company does not expect to make any significant tax payment related to any of the above obligations within the next twelve months.

 
18
 
 


7.
OTHER INCOME AND (INCOME DEDUCTIONS) – NET
 


     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Allowance for funds used during construction
 
$
(16
)
$
(2
)
$
(25
)
$
(16
)
 
Interest income
   
1,047
   
1,292
   
2,820
   
3,237
 
 
Other income
   
183
   
224
   
720
   
546
 
 
Other income deductions
   
(138
)
 
(440
)
 
210
   
609
 
 
Other Income and (Income Deductions) – Net
 
$
1,076
 
$
1,074
 
$
3,725
 
$
4,376
 
 
The decrease in Other Income and (Income Deductions) – Net for the six months ended March 31, 2008, compared with the six months ended March 31, 2007, was primarily due to lower income associated with carrying costs applied to under-recoveries of gas costs, reduced income associated with changes in the cash surrender value of life insurance policies, and higher investment losses, partially offset by a reversal of tax-related expenses. Carrying costs on under-recoveries of gas costs are recovered through the Utility’s Purchased Gas Adjustment (PGA) Clause.


8.
INFORMATION BY OPERATING SEGMENT

All of Laclede Group’s subsidiaries are wholly owned. The Regulated Gas Distribution segment consists of the regulated operations of Laclede Gas and is the core business segment of Laclede Group. Laclede Gas is a public utility engaged in the retail distribution and sale of natural gas serving an area in eastern Missouri, with a population of approximately 2.1 million, including the City of St. Louis and parts of ten other counties in eastern Missouri. The Non-Regulated Gas Marketing segment includes the results of LER, a subsidiary engaged in the non-regulated marketing of natural gas and related activities. Other includes Laclede Pipeline Company’s transportation of liquid propane regulated by the Federal Energy Regulatory Commission (FERC) as well as non-regulated activities, including real estate development, the compression of natural gas, and financial investments in other enterprises. These operations are conducted through five subsidiaries. Other also includes Laclede Gas’ non-regulated merchandise sales business. Certain intersegment revenues with Laclede Gas are not eliminated in accordance with the provisions of SFAS No. 71, “Accounting for the Effects of Certain Types of Regulation.” Those types of transactions include sales of natural gas from Laclede Gas to LER, sales of natural gas from LER to Laclede Gas, and transportation services provided by Laclede Pipeline Company to Laclede Gas. These revenues are shown on the Intersegment revenues lines in the table under Regulated Gas Distribution, Non-Regulated Gas Marketing, and Other columns, respectively.
Previously, SM&P comprised the Non-Regulated Services segment and its financial information was presented separately. As discussed in Note 2, Discontinued Operations, the Company sold SM&P on March 31, 2008. Accordingly, financial information for this segment has been reclassified and reported as discontinued operations in the Consolidated Financial Statements. Under generally accepted accounting principles, general corporate overhead expenses may not be reported in discontinued operations. Amounts of such expenses that were previously reported by SM&P but that are required to be reported in continuing operations are reflected in the “Unallocated & Eliminations” column of the table below. Prior periods reported in the table below have been reclassified to conform to the current-period presentation of segment information.











 
19
 
 



 

       
Non-
             
   
Regulated
 
Regulated
     
Unallocated
     
   
Gas
 
Gas
     
 &
     
(Thousands)
 
Distribution
 
Marketing
 
Other
 
Eliminations
 
Consolidated
 
Three Months Ended
                               
March 31, 2008
                               
Revenues from external
                               
  customers
 
$
507,031
 
$
237,748
 
$
971
 
$
 
$
745,750
 
Intersegment revenues
   
58
   
1,639
   
259
   
   
1,956
 
Total operating revenues
   
507,089
   
239,387
   
1,230
   
   
747,706
 
Income (loss) from continuing
                               
  operations
   
25,331
   
4,861
   
38
   
(170
)
 
30,060
 
Total assets of continuing
                               
  operations
   
1,454,369
   
152,256
   
175,976
   
(76,737
)
 
1,705,864
 
                                 
Six Months Ended
                               
March 31, 2008
                               
Revenues from external
                               
  customers
 
$
826,705
 
$
416,408
 
$
2,011
 
$
 
$
1,245,124
 
Intersegment revenues
   
1,276
   
4,777
   
519
   
   
6,572
 
Total operating revenues
   
827,981
   
421,185
   
2,530
   
   
1,251,696
 
Income (loss) from continuing
                               
  operations
   
41,078
   
10,515
   
267
   
(264
)
 
51,596
 
Total assets of continuing
                               
  operations
   
1,454,369
   
152,256
   
175,976
   
(76,737
)
 
1,705,864
 
                                 
Three Months Ended
                               
March 31, 2007
                               
Revenues from external
                               
  customers
 
$
483,254
 
$
157,837
 
$
998
 
$
 
$
642,089
 
Intersegment revenues
   
10,339
   
18,013
   
259
   
   
28,611
 
Total operating revenues
   
493,593
   
175,850
   
1,257
   
   
670,700
 
Income (loss) from continuing
                               
  operations
   
20,711
   
3,322
   
149
   
(173
)
 
24,009
 
Total assets of continuing
                               
  operations
   
1,370,644
   
113,825
   
75,588
   
(67,214
)
 
1,492,843
 
                                 
Six Months Ended
                               
March 31, 2007
                               
Revenues from external
                               
  customers
 
$
823,710
 
$
295,525
 
$
1,915
 
$
 
$
1,121,150
 
Intersegment revenues
   
18,371
   
33,792
   
519
   
   
52,682
 
Total operating revenues
   
842,081
   
329,317
   
2,434
   
   
1,173,832
 
Income (loss) from continuing
                               
  operations
   
36,368
   
7,117
   
288
   
(356
)
 
43,417
 
Total assets of continuing
                               
  operations
   
1,370,644
   
113,825
   
75,588
   
(67,214
)
 
1,492,843
 



 
20
 
 



9.
COMMITMENTS AND CONTINGENCIES

Laclede Gas owns and operates natural gas distribution, transmission and storage facilities, the operations of which are subject to various environmental laws, regulations and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Company’s or Laclede Gas’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas may be required to incur additional costs. See Note 14 to the Consolidated Financial Statements included in the Company’s Fiscal Year 2007 Form 10-K for information relative to environmental matters generally. There have been no significant changes relative to environmental matters during the six months ended March 31, 2008.
On December 28, 2006, the MoPSC Staff proposed a disallowance of $7.2 million related to Laclede Gas’ recovery of its purchased gas costs applicable to fiscal 2005. On September 14, 2007, the Staff withdrew its pursuit of $5.5 million of the disallowance it had originally proposed. Laclede Gas believes that the remaining $1.7 million of the MoPSC Staff’s proposed disallowance lacks merit and intends to vigorously oppose the adjustment in proceedings before the MoPSC.
On December 31, 2007, the MoPSC Staff filed a memorandum with the Commission proposing a disallowance of $2.8 million related to the Company’s recovery of its purchased gas costs applicable to fiscal 2006. Laclede Gas believes that the MoPSC Staff’s position lacks merit and intends to vigorously oppose the adjustment in proceedings before the MoPSC. In addition, the MoPSC’s Staff’s memorandum raised questions regarding whether certain sales and capacity release transactions subject to the FERC’s oversight were consistent with the FERC’s regulations and policies regarding capacity release. The Company has commenced an internal review of the questions raised by the MoPSC Staff and has notified the FERC Staff that it has taken this action.
As reported in Note 2, Discontinued Operations, during the quarter ended March 31, 2008, the Company sold 100% of its interest in its wholly-owned subsidiary SM&P. The sales agreement (Agreement) includes representations and warranties customary for such transactions, including, among others, representations and warranties of the parties as to brokers’ fees; of SM&P as to its financial status, contracts, title to and condition of personal and real property, taxes, legal compliance, environmental matters, employee benefits, and intellectual property. The Agreement also includes customary indemnification provisions under which Laclede’s aggregate indemnification obligations are limited to a maximum of $7 million for most claims. Obligations subject to this maximum apply only in the event claims exceed a stated deductible, both individually and in the aggregate. However, this maximum limitation and deductible do not apply to obligations associated with taxes, employee benefits, title to personal property, and certain other fundamental representations and warranties. A maximum potential future payment amount cannot be estimated for these obligations. The terms of the indemnifications in the Agreement are generally dependent upon the statute of limitations applicable to the particular representations and warranties made by the Company, although certain representations and warranties have an indefinite life under the Agreement. As of March 31, 2008, the carrying amount of the liability recognized for these indemnification obligations was $0.2 million, based on the Company’s assessment of risk.
Laclede Group is involved in other litigation, claims and investigations arising in the normal course of business. While the results of such litigation cannot be predicted with certainty, management, after discussion with counsel, believes that the final outcome will not have a material adverse effect on the consolidated financial position or results of operations of the Company.
Laclede Gas has several operating leases for the rental of vehicles that contain provisions requiring Laclede Gas to guarantee certain amounts related to the residual value of the leased property. These leases have various terms, the longest of which extends through 2014. At March 31, 2008, the maximum guarantees under these leases are $1.7 million. However, the Utility estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At March 31, 2008, the carrying value of the liability recognized for these guarantees was $0.3 million.
SM&P has several operating leases, the aggregate annual cost of which is $8.2 million, consisting primarily of 12-month operating leases, with renewal options, for vehicles used in its business. Laclede Group previously had parental guarantees of certain of those vehicle leases but was released from those guarantees on or before March 31, 2008, concurrent with the sale of SM&P.
Laclede Gas and LER have entered into various contracts, expiring on dates through 2017, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at March 31, 2008 are estimated at approximately $2.3 billion. Additional contracts are generally entered into prior to or during the heating season.
Laclede Group had guarantees totaling $50.0 million for performance and payment of certain wholesale gas supply purchases by LER, as of March 31, 2008. Since that date, total guarantees issued by Laclede Group on behalf of LER decreased by $1.0 million bringing the total to $49.0 million in guarantees outstanding at April 23, 2008. No amounts have been recorded for these guarantees in the financial statements.

 
21
 
 



10.
SUBSEQUENT EVENT

In fiscal year 2003, Laclede Group formed Laclede Capital Trust I (Trust), its affiliated, nonconsolidated trust, for the sole purpose of issuing trust securities and investing the gross proceeds of the sale of the trust securities in debt securities of Laclede Group. All of the Trust securities have a liquidation value of $25 per share and a dividend rate of 7.70%, with all of its common securities being owned by Laclede Group and all of its preferred securities being sold to the public. The Trust’s sole asset is the Company’s $46.4 million aggregate principal amount of 7.70% debentures due December 1, 2032 (Debentures), which have the same economic terms as the Trust securities and are reflected as long-term debt to unconsolidated affiliate trust on the Consolidated Balance Sheets. The Company’s investment in the Trust common securities is included on the Other Investments line on the Consolidated Balance Sheets.
On April 1, 2008, Laclede Group announced the redemption in full of its Debentures on May 5, 2008 (redemption date), which also triggers the redemption of all of the Trust common and preferred securities on the redemption date. Interest on the Debentures and distributions on the Trust securities will cease to accrue on and after the redemption date. Upon redemption, Laclede Group anticipates recognizing a pre-tax loss of approximately $1.3 million attributable to unamortized debt issuance costs. A portion of the proceeds received from the sale of SM&P will be used to fund the redemption.

Laclede Gas Company’s Financial Statements and Notes to Financial Statements are included in Exhibit 99.1 to this report.


 
22
 
 

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

THE LACLEDE GROUP, INC.

This management’s discussion analyzes the financial condition and results of operations of The Laclede Group, Inc. (Laclede Group or the Company) and its subsidiaries. It includes management’s view of factors that affect its business, explanations of past financial results including changes in earnings and costs from the prior year periods, and their effects on overall financial condition and liquidity.

Certain matters discussed in this report, excluding historical information, include forward-looking statements. Certain words, such as “may,” “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan,” “seek,” and similar words and expressions identify forward-looking statements that involve uncertainties and risks. Future developments may not be in accordance with our expectations or beliefs and the effect of future developments may not be those anticipated. Among the factors that may cause results to differ materially from those contemplated in any forward-looking statement are:

weather conditions and catastrophic events, particularly severe weather in the natural gas producing areas of the country;
volatility in gas prices, particularly sudden and sustained spikes in natural gas prices;
the impact of higher natural gas prices on our competitive position in relation to suppliers of alternative heating sources, such as electricity;
changes in gas supply and pipeline availability; particularly those changes that impact supply for and access to our market area;
legislative, regulatory and judicial mandates and decisions, some of which may be retroactive, including those affecting
 
allowed rates of return
 
incentive regulation
 
industry structure
 
purchased gas adjustment provisions
 
rate design structure and implementation
 
franchise renewals
 
environmental or safety matters
 
taxes
 
pension and other postretirement benefit liabilities and funding obligations
 
accounting standards;
the results of litigation;
retention of, ability to attract, ability to collect from and conservation efforts of customers;
capital and energy commodity market conditions, including the ability to obtain funds for necessary capital expenditures and general operations and the terms and conditions imposed for obtaining sufficient gas supply;
discovery of material weakness in internal controls; and
employee workforce issues.

Readers are urged to consider the risks, uncertainties and other factors that could affect our business as described in this report. All forward-looking statements made in this report rely upon the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. We do not, by including this statement, assume any obligation to review or revise any particular forward-looking statement in light of future events.

The Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the Company’s Consolidated Financial Statements and the Notes thereto.







 
23
 
 


THE LACLEDE GROUP, INC.

RESULTS OF OPERATIONS

Laclede Group’s earnings are primarily derived from the regulated activities of its largest subsidiary, Laclede Gas Company (Laclede Gas or the Utility), Missouri’s largest natural gas distribution company. Laclede Gas is regulated by the Missouri Public Service Commission (MoPSC or Commission) and serves the City of St. Louis and parts of ten other counties in eastern Missouri. Laclede Gas delivers natural gas to retail customers at rates, and in accordance with tariffs, authorized by the MoPSC. The Utility’s earnings are primarily generated by the sale of heating energy. The Utility’s innovative weather mitigation rate design lessens the impact of weather volatility on Laclede Gas customers during cold winters and stabilizes the Utility’s earnings by recovering fixed costs more evenly during the heating season. Due to the seasonal nature of the business of Laclede Gas, Laclede Group’s earnings are seasonal in nature and are typically concentrated in the November through April period, which generally corresponds with the heating season.

On March 31, 2008, the Company completed the sale of 100% of its interest in its wholly-owned subsidiary SM&P Utility Resources, Inc. (SM&P) to Stripe Acquisition, Inc. (an affiliate of Kohlberg Management VI, LLC) for $85 million in cash, subject to certain closing and post-closing adjustments. SM&P is an underground facilities locating and marking business that comprised Laclede Group’s Non-Regulated Services operating segment. The sales agreement included representations, warranties, and indemnification provisions customary for such transactions and is filed as an exhibit to this Form 10-Q. In accordance with generally accepted accounting principles, the results of operations for SM&P are reported as discontinued operations in the Consolidated Statements of Income and its associated assets and liabilities are classified separately in the Consolidated Balance Sheets.

Laclede Energy Resources, Inc. (LER) is engaged in the non-regulated marketing of natural gas and related activities. LER markets natural gas to both on-system Utility transportation customers and customers outside of Laclede Gas’ traditional service territory, including large retail and wholesale customers. As such, LER’s operations and customer base are subject to fluctuations in market conditions.

Other subsidiaries provide less than 10% of consolidated revenues.

Laclede Group’s strategy continues to include efforts to stabilize and improve the performance of its core Utility, while developing non-regulated businesses and taking a measured approach in the pursuit of additional growth opportunities that complement the Utility business.

As for the Utility, mitigating the impact of weather fluctuations on Laclede Gas customers while improving the ability to recover its authorized distribution costs and return continues to be a fundamental component of Laclede Group’s strategy. The Utility’s distribution costs are the essential, primarily fixed expenditures it must incur to operate and maintain a more than 16,000 mile natural gas distribution system and related storage facilities. In addition, Laclede Gas is working to continually improve its ability to provide reliable natural gas service at a reasonable cost, while maintaining and building a secure and dependable infrastructure. The settlement of the Utility’s 2007 rate case resulted in enhancements to the Utility’s weather mitigation rate design that better ensure the recovery of its fixed costs and margins despite variations in sales volumes due to the impacts of weather and other factors that affect customer usage. The Utility’s income from off-system sales remains subject to fluctuations in market conditions. In conjunction with the settlement of the 2005 rate case, effective October 1, 2005, the Utility retained all pre-tax income from off-system sales and capacity release revenues up to $12 million annually. Pre-tax amounts in excess of $12 million were shared with customers, with the Utility retaining 50% of amounts exceeding that threshold. The Stipulation & Agreement approved by the MoPSC in the Utility’s 2007 rate case increases the portion of pre-tax income from off-system sales and capacity release revenues that is shared with customers. Effective October 1, 2007, the Utility is allowed to retain 15% to 25% of the first $6 million in annual income earned (depending on the level of income earned) and 30% of income exceeding $6 million annually. Some of the factors impacting the level of off-system sales include the availability and cost of the Utility’s natural gas supply, the weather in its service area, and the weather in other markets. When Laclede Gas’ service area experiences warmer-than-normal weather while other markets experience colder weather or supply constraints, some of the Utility’s natural gas supply is available for off-system sales and there may be a demand for such supply in other markets.

Laclede Gas continues to work actively to reduce the impact of higher costs associated with wholesale natural gas prices by strategically structuring its natural gas supply portfolio and through the use of financial instruments. Nevertheless, the cost of purchased gas remains high, relative to historical levels. The Utility’s Purchased Gas Adjustment (PGA) Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies, including costs, cost reductions, and related carrying costs associated with the use of financial instruments to hedge the purchase price of natural gas, as well as gas inventory carrying costs. The Utility believes it will continue to be able to

 
24
 
 

obtain sufficient gas supply. The generally higher price levels may continue to affect sales volumes (due to the conservation efforts of customers) and cash flows (associated with the timing of collection of gas costs and related accounts receivable from customers).

Laclede Group continues to develop its other subsidiaries. LER continues to focus on growing its markets on a long-term and sustainable basis by providing both on-system Utility transportation customers and customers outside of Laclede Gas’ traditional service area with another choice in non-regulated natural gas suppliers. Nevertheless, income from LER’s operations is subject to fluctuations in market conditions.

Quarter Ended March 31, 2008

Earnings

 Overview – Net Income (Loss) by Operating Segment
     
Quarter Ended
 
       
March 31,
 
(millions, after-tax)
       
2008
       
2007
 
                       
Regulated Gas Distribution
     
$
25.3
     
$
20.7
 
Non-Regulated Gas Marketing
       
4.9
       
3.3
 
Other
       
(0.1
)
     
 
Income from Continuing Operations
       
30.1
       
24.0
 
Income (Loss) from Discontinued Operations
       
21.3
       
(3.2
)
Net Income
     
$
51.4
     
$
20.8
 

Laclede Group’s consolidated net income was $51.4 million for the quarter ended March 31, 2008, compared with $20.8 million for the quarter ended March 31, 2007. Basic and diluted earnings per share were $2.38 and $2.37, respectively, for the quarter ended March 31, 2008 compared with basic and diluted earnings per share of $0.97 for the quarter ended March 31, 2007. Earnings per share increased compared to last year largely due to the one-time gain realized on the sale of Laclede Group’s wholly-owned subsidiary, SM&P. Earnings results reported by both Laclede Group’s regulated gas distribution segment and its non-regulated gas marketing segment also increased as compared to performance in the quarter ended March 31, 2007.

Income from Continuing Operations

Laclede Group’s income from continuing operations was $30.1 million for the quarter ended March 31, 2008, compared with $24.0 million for the quarter ended March 31, 2007. Basic and diluted earnings per share from continuing operations were $1.39 for the quarter ended March 31, 2008 compared with basic and diluted earnings per share of $1.12 for the quarter ended March 31, 2007. Earnings results reported by both Laclede Group’s regulated gas distribution segment and its non-regulated gas marketing segment increased over the quarter ended March 31, 2007. Variations in income from continuing operations were primarily attributable to the factors described below.

Regulated Gas Distribution net income increased by $4.6 million for the quarter ended March 31, 2008, compared with the quarter ended March 31, 2007. The increase in net income was primarily due to the following factors, quantified on a pre-tax basis:


the benefit of the general rate increase, effective August 1, 2007, totaling $11.5 million; and,
the recognition of previously unrecognized tax benefits and the reversal of related expenses, totaling $1.1 million.

These factors were partially offset by:

lower income from off-system sales and capacity release, totaling $4.2 million, primarily due to a reduction in the Utility’s share of such income (pursuant to the 2007 rate case); and,
an increase in the provision for uncollectible accounts, totaling $1.8 million.

The Non-Regulated Gas Marketing segment reported an increase in earnings of $1.6 million compared with the same quarter last year, primarily due to the benefit of a reversal in tax-related expenses during the quarter and higher sales volumes, partially offset by lower margins on sales of natural gas by LER.

 
25
 
 


Regulated Operating Revenues and Operating Expenses

Laclede Gas passes on to Utility customers (subject to prudence review) increases and decreases in the wholesale cost of natural gas in accordance with its PGA Clause. The volatility of the wholesale natural gas market results in fluctuations from period to period in the recorded levels of, among other items, revenues and natural gas cost expense. Nevertheless, increases and decreases in the cost of gas associated with system gas sales volumes have no direct effect on net revenues and net income.

Regulated operating revenues for the quarter ended March 31, 2008 were $507.1 million, or $13.5 million more than the same quarter last year. Temperatures experienced in the Utility’s service area during the quarter were 10.1% colder than the same quarter last year and 1.0% colder than normal. Total system therms sold and transported were 0.45 billion for the quarter ended March 31, 2008 compared with 0.40 billion for the same quarter last year. Total off-system therms sold and transported were 0.06 billion for the quarter ended March 31, 2008 compared with 0.09 billion for the same quarter last year. The increase in regulated operating revenues was primarily attributable to the following factors:

   
Millions
 
Higher system sales volumes, primarily due to colder weather, and other variations
 
$
42.6
 
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
   
(26.6
)
Lower off-system sales volumes
   
(24.0
)
General rate increase, effective August 1, 2007
   
11.5
 
Higher prices charged for off-system sales
   
10.6
 
Lower Infrastructure System Replacement Surcharge (ISRS) revenues
   
(0.6
)
Total Variation
 
$
13.5
 

Regulated operating expenses for the quarter ended March 31, 2008 increased $7.0 million from the same quarter last year. Natural and propane gas expense increased $4.0 million, or 1.1%, from last year’s level, primarily attributable to higher system volumes purchased for sendout, partially offset by lower rates charged by our suppliers and lower off-system gas expense. Other operation and maintenance expenses increased $1.9 million, or 4.5%, primarily due to a higher provision for uncollectible accounts, the effect of a gain on the disposal of assets recorded last year, and higher wage rates. These factors were partially offset by decreased maintenance and distribution charges. Taxes, other than income, increased $0.9 million, or 3.2%, primarily due to higher gross receipts taxes (attributable to the increased revenues).

Non-Regulated Gas Marketing Operating Revenues and Operating Expenses

Non-regulated gas marketing operating revenues increased $63.5 million primarily due to increased sales volumes and increased per unit gas sales prices charged by LER. The increase in non-regulated gas marketing operating expenses totaling $63.1 million was primarily associated with increased volumes purchased and higher prices charged by suppliers.

Interest Charges

The $1.6 million decrease in interest charges was primarily due to a reduction in interest on long-term debt resulting from the November 2007 maturity of $40 million principal amount of 7 1/2% First Mortgage Bonds and the reversal of tax-related expenses.

Income Taxes

The $2.5 million increase in income taxes was primarily due to higher pre-tax income, partially offset by the recognition of previously unrecognized tax benefits recorded pursuant to Financial Accounting Standards Board Interpretation No. 48 (FIN 48), “Accounting for Uncertainty in Income Taxes.”

Income (Loss) from Discontinued Operations

Laclede Group closed on the sale of 100% of its interest in SM&P on March 31, 2008. The sale resulted in after-tax earnings of $25.8 million, net of associated costs of disposal, subject to a minor post-closing adjustment, the amount of which is yet to be determined. Income from discontinued operations for the quarter ended March 31, 2008 was $21.3 million, consisting of the net effect of the sale and SM&P’s seasonal operating loss, compared with a loss of $3.2 million for the quarter ended March 31, 2007. Basic and diluted earnings per share from discontinued operations were $0.99 and $0.98, respectively, for the quarter ended March 31, 2008 compared with a basic and diluted loss of $0.15 per share for the same period last year.

 
26
 
 


Six Months Ended March 31, 2008

Earnings
 
Overview – Net Income (Loss) by Operating Segment
     
Six Months Ended
 
       
March 31,
 
(millions, after-tax)
       
2008
       
2007
 
                       
Regulated Gas Distribution
     
$
41.1
     
$
36.4
 
Non-Regulated Gas Marketing
       
10.5
       
7.1
 
Other
       
       
(0.1
)
Income from Continuing Operations
       
51.6
       
43.4
 
Income (Loss) from Discontinued Operations
       
20.7
       
(3.5
)
Net Income
     
$
72.3
     
$
39.9
 

Laclede Group’s consolidated net income was $72.3 million for the six months ended March 31, 2008, compared with $39.9 million for the six months ended March 31, 2007. Basic and diluted earnings per share were $3.35 and $3.34, respectively, for the six months ended March 31, 2008 compared with basic and diluted earnings per share of $1.86 for the six months ended March 31, 2007. Earnings per share increased compared to last year largely due to the one-time gain realized on the sale of Laclede Group’s wholly-owned subsidiary, SM&P. Earnings results reported by both Laclede Group’s regulated gas distribution segment and its non-regulated gas marketing segment also increased over the six months ended March 31, 2007.

Income from Continuing Operations

Laclede Group’s income from continuing operations was $51.6 million for the six months ended March 31, 2008, compared with $43.4 million for the six months ended March 31, 2007. Basic and diluted earnings per share from continuing operations were $2.39 and $2.38, respectively, for the six months ended March 31, 2008 compared with basic and diluted earnings per share of $2.03 and $2.02, respectively, for the six months ended March 31, 2007. Earnings results reported by both Laclede Group’s regulated gas distribution segment and its non-regulated gas marketing segment increased over the same period last year. Variations in income from continuing operations were primarily attributable to the factors described below.

Regulated Gas Distribution net income increased by $4.7 million for the six months ended March 31, 2008, compared with the six months ended March 31, 2007. The benefit of the general rate increase effective August 1, 2007, totaling $21.6 million, was partially offset by the following factors, quantified on a pre-tax basis:

lower income from off-system sales and capacity release, totaling $7.5 million, primarily due to a reduction in the Utility’s share of such income (pursuant to the 2007 rate case);
the net effect of lower system gas sales margins, primarily due to an unusually late start to the heating season, and other variations totaling $2.7 million;
an increase in the provision for uncollectible accounts, totaling $2.3 million; and,
increases in operation and maintenance expenses totaling $1.8 million.

The Non-Regulated Gas Marketing segment reported an increase in earnings of $3.4 million for the six months ended March 31, 2008, compared with the same period last year, primarily due to the reversal of tax-related expenses, increased sales volumes, and higher margins on sales of natural gas by LER.

Regulated Operating Revenues and Operating Expenses

Regulated operating revenues for the six months ended March 31, 2008 were $828.0 million, or $14.1 million less than the same period last year. Temperatures experienced in the Utility’s service area during the six months ended March 31, 2008 were 5.9% colder than the same period last year, but 2.9% warmer than normal. Total system therms sold and transported were 0.72 billion for the six months ended March 31, 2008 compared with 0.68 billion for the same period last year. Total off-system therms sold and transported were 0.11 billion for the six months ended March 31, 2008 compared with 0.15 billion for the same period last year. Increases and decreases in the cost of gas associated with system gas sales volumes have no direct effect on net revenues and net income. The decrease in regulated operating revenues was primarily attributable to the following factors:

 
27
 
 



   
Millions
 
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
 
$
(43.2
)
Lower off-system sales volumes
   
(33.3
)
Higher system sales volumes, primarily due to colder weather, and other variations
   
30.2
 
General rate increase, effective August 1, 2007
   
21.6
 
Higher prices charged for off-system sales
   
11.7
 
Lower ISRS revenues
   
(1.1
)
Total Variation
 
$
(14.1
)

Regulated operating expenses for the six months ended March 31, 2008 decreased $21.4 million from the same period last year. Natural and propane gas expense decreased $24.7 million, or 4.0%, from last year’s level, primarily attributable to lower rates charged by our suppliers and lower off-system gas expense, partially offset by increased system volumes purchased for sendout. Other operation and maintenance expenses increased $4.1 million, or 5.0%, primarily due to a higher provision for uncollectible accounts, higher injuries and damages expense, the effect of a gain on the disposal of assets recorded last year, increased pension costs, and higher wage rates. These factors were partially offset by lower group insurance charges and other variations. Depreciation and amortization expense increased $0.4 million, or 2.4%, primarily due to additional depreciable property. Taxes, other than income, decreased $1.2 million, or 2.5%, primarily due to decreased gross receipts taxes and lower property taxes.

Non-Regulated Gas Marketing Operating Revenues and Operating Expenses

Non-regulated gas marketing operating revenues increased $91.9 million primarily due to increased sales volumes and higher per unit gas sales prices charged by LER. The increase in non-regulated gas marketing operating expenses totaling $88.3 million was primarily associated with increased volumes purchased and higher prices charged by suppliers.

Other Income and (Income Deductions) – Net

The $0.7 million decrease in other income and income deductions – net was primarily due to lower income associated with carrying costs applied to under-recoveries of gas costs, reduced income associated with changes in the cash surrender value of life insurance policies, and higher investment losses, partially offset by a reversal of tax-related expenses. Carrying costs on under-recoveries of gas costs are recovered through the Utility’s Purchased Gas Adjustment Clause.

Interest Charges

The $1.4 million decrease in interest charges was primarily due to a reduction in interest on long-term debt resulting from the November 2007 maturity of $40 million principal amount of 7 1/2% First Mortgage Bonds and the reversal of tax-related expenses, partially offset by higher interest on short-term debt. Average short-term interest rates were 4.7% for the six months ended March 31, 2008 compared with 5.3% for the same period last year. Average short-term borrowings were $236.4 million and $190.7 million for the six months ended March 31, 2008 and 2007, respectively.

Income Taxes

The $3.6 million increase in income taxes was primarily due to higher pre-tax income, partially offset by the recognition of previously unrecognized tax benefits recorded pursuant to FIN 48.

Income (Loss) from Discontinued Operations

Income from discontinued operations for the six months ended March 31, 2008 was $20.7 million, consisting of the net effect of the aforementioned sale and SM&P’s operating loss for the period, compared with a loss of $3.5 million for the same period last year. Basic and diluted earnings per share from discontinued operations were $0.96 for the six months ended March 31, 2008 compared with a basic and diluted loss of $0.17 and $0.16 per share, respectively, for the same period last year.


 
28
 
 

REGULATORY MATTERS

During fiscal 2006, the MoPSC approved permanent modifications to the Cold Weather Rule affecting the disconnection and reconnection practices of utilities during the winter heating season. Those modifications included provisions to allow the Utility to obtain accounting authorizations and defer for future recovery certain costs incurred with the modifications. During fiscal 2007, the Utility deferred for future recovery $2.7 million of costs associated with the fiscal 2007 heating season. On October 31, 2007, the Utility filed for determination and subsequent recovery of the deferred amount. On November 16, 2007, the MoPSC directed the MoPSC Staff and the Missouri Office of Public Counsel to submit their positions regarding the Utility’s filing by February 28, 2008. On February 28, 2008, the Utility and MoPSC Staff filed a Non-unanimous Stipulation & Agreement in which these parties agreed to a recovery of $2.5 million of costs. The Non-unanimous Stipulation & Agreement was opposed by the Office of the Public Counsel, and a hearing in this matter was held before the Commission on March 31, 2008. On April 17, 2008, the Commission issued its Report and Order in which it determined that the $2.5 million of costs recommended by the Utility and MoPSC Staff was reasonable and would be approved. Consistent with the approved amount, the Utility recorded a reduction in its deferral totaling $0.2 million during the quarter ended March 31, 2008.

On November 9, 2007, the Utility made an ISRS filing with the Commission designed to increase revenues by $1.6 million annually. On January 15, 2008, the Commission approved implementation of the surcharge to be effective January 18, 2008. On April 25, 2008, the Utility made an ISRS filing with the Commission designed to increase revenues by $1.9 million annually, pending approval by the Commission.

On December 28, 2006, the MoPSC Staff proposed a disallowance of $7.2 million related to Laclede Gas’ recovery of its purchased gas costs applicable to fiscal 2005. On September 14, 2007, the Staff withdrew its pursuit of $5.5 million of the disallowance it had originally proposed. Laclede Gas believes that the remaining $1.7 million of the MoPSC Staff’s proposed disallowance lacks merit and intends to vigorously oppose the adjustment in proceedings before the MoPSC.

On December 31, 2007, the MoPSC Staff filed a memorandum with the Commission proposing a disallowance of $2.8 million related to the Company’s recovery of its purchased gas costs applicable to fiscal 2006. Laclede Gas believes that the MoPSC Staff’s position lacks merit and intends to vigorously oppose the adjustment in proceedings before the MoPSC. In addition, the MoPSC’s Staff’s memorandum raised questions regarding whether certain sales and capacity release transactions subject to the Federal Energy Regulatory Commission (FERC)’s oversight were consistent with the FERC’s regulations and policies regarding capacity release. The Company has commenced an internal review of the questions raised by the MoPSC Staff and has notified the FERC Staff that it has taken this action.


CRITICAL ACCOUNTING POLICIES

Our discussion and analysis of our financial condition, results of operations, liquidity, and capital resources is based upon our consolidated financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. Generally accepted accounting principles require that we make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We evaluate our estimates on an ongoing basis. We base our estimates on historical experience and on various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates. We believe the following represent the more significant items requiring the use of judgment and estimates in preparing our consolidated financial statements:

 
Allowances for doubtful accounts – Estimates of the collectibility of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. The Utility’s provision for uncollectible accounts is dependent on the regulatory treatment provided for such costs. As approved by the MoPSC, the Utility is allowed to defer for future recovery certain costs associated with amendments to the Cold Weather Rule.
   
 
Employee benefits and postretirement obligations – Pension and postretirement obligations are calculated by actuarial consultants that utilize several statistical factors and other assumptions related to future events, such as discount rates, returns on plan assets, compensation increases, and mortality rates. For the Utility, the amount of expense recognized and the amounts reflected in other comprehensive income are dependent upon the regulatory treatment provided for such costs, as discussed further below. Certain liabilities related to group medical benefits and workers’ compensation claims, portions of which are self-insured and/or contain “stop-loss” coverage with third-party insurers to limit exposure, are established based on historical trends.


 
29
 
 


Laclede Gas accounts for its regulated operations in accordance with Statement of Financial Accounting Standards (SFAS) No. 71, “Accounting for the Effects of Certain Types of Regulation.” This Statement sets forth the application of accounting principles generally accepted in the United States of America for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of SFAS No. 71 require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of SFAS No. 71 and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. Management believes the following represent the more significant items recorded through the application of SFAS No. 71:

 
The Utility’s PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies, including the costs, cost reductions, and related carrying costs associated with the Utility’s use of natural gas financial instruments to hedge the purchase price of natural gas. The difference between actual costs incurred and costs recovered through the application of the PGA are recorded as regulatory assets and regulatory liabilities that are recovered or refunded in a subsequent period. The PGA Clause also authorizes the Utility to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. The PGA Clause also permits the application of carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of financial instruments. Effective October 1, 2007, the PGA Clause also provides for a portion of income from off-system sales and capacity release revenues to be flowed through to customers.
   
 
The Company records deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes, and the amounts used for income tax purposes. Changes in enacted tax rates, if any, and certain property basis differences will be reflected by entries to regulatory asset or liability accounts for regulated companies, and will be reflected as income or loss for non-regulated companies. Pursuant to the direction of the MoPSC, Laclede Gas’ provision for income tax expense for financial reporting purposes reflects an open-ended method of tax depreciation. Laclede Gas’ provision for income tax expense also records the income tax effect associated with the difference between overheads capitalized to construction for financial reporting purposes and those recognized for tax purposes without recording an offsetting deferred income tax expense. These two methods are consistent with the regulatory treatment prescribed by the MoPSC.
   
 
Asset retirement obligations are recorded in accordance with SFAS No. 143, “Accounting for Asset Retirement Obligations” and FIN 47, “Accounting for Conditional Asset Retirement Obligations.” Asset retirement obligations are calculated using various assumptions related to the timing, method of settlement, inflation, and profit margins that third parties would demand to settle the future obligations. These assumptions require the use of judgment and estimates and may change in future periods as circumstances dictate. As authorized by the MoPSC, Laclede Gas accrues future removal costs associated with its property, plant and equipment through its depreciation rates, even if a legal obligation does not exist as defined by SFAS No. 143 and FIN 47. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognizable under SFAS No. 143 and FIN 47 is a timing difference between the recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, consistent with SFAS No. 71, these differences are deferred as regulatory liabilities.

 
The amount of net periodic pension and other postretirement benefit cost recognized in the financial statements related to the Utility’s qualified pension plans and other postretirement benefit plans is based upon allowances, as approved by the MoPSC, which have been established in the rate-making process for the recovery of these costs from customers. The differences between these amounts and actual pension and other postretirement benefit costs incurred for financial reporting purposes are deferred as regulatory assets or regulatory liabilities. SFAS No. 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans,” requires that changes that affect the funded status of pension and other postretirement benefit plans, but that are not yet required to be recognized as components of pension and other postretirement benefit cost, be reflected in other comprehensive income. For the Utility’s qualified pension plans and other postretirement benefit plans, amounts that would otherwise be reflected in other comprehensive income are deferred with entries to regulatory assets or regulatory liabilities.


 
30
 
 


For further discussion of significant accounting policies, see Note 1 to the Consolidated Financial Statements included in the Company’s Form 10-K for the fiscal year ended September 30, 2007.


ACCOUNTING PRONOUNCEMENTS

The Company has evaluated or is in the process of evaluating the impact that recently issued accounting standards will have on the Company’s financial position or results of operations upon adoption. For disclosures related to the adoption of new accounting standards, see the New Accounting Standards section of Note 1 to the Consolidated Financial Statements.


FINANCIAL CONDITION


CREDIT RATINGS

As of March 31, 2008, credit ratings for outstanding securities for Laclede Group and Laclede Gas issues were as follows:

Type of Facility
S&P
Moody’s
Fitch
Laclede Group Corporate Rating
A
 
A-
Laclede Gas First Mortgage Bonds
A
A3
A+
Laclede Gas Commercial Paper
A-1
P-2
 
Laclede Capital Trust I Trust Preferred Securities
A-
Baa3
BBB+

The Company has investment grade ratings, and believes that it will have adequate access to the financial markets to meet its capital requirements. These ratings remain subject to review and change by the rating agencies.


CASH FLOWS

The Company’s short-term borrowing requirements typically peak during colder months when Laclede Gas borrows money to cover the lag between when it purchases its natural gas and when its customers pay for that gas. Changes in the wholesale cost of natural gas, variations in the timing of collections of gas cost under the Utility’s PGA Clause, the seasonality of accounts receivable balances, and the utilization of storage gas inventories cause short-term cash requirements to vary during the year, and can cause significant variations in the Utility’s cash provided by or used in operating activities.

Net cash provided by operating activities for the six months ended March 31, 2008 was $130.8 million, compared with $114.0 million for the same period last year. The variation is primarily attributable to improved operating cash flows at LER and a reduction in net cash payments associated with the Utility’s use of natural gas financial instruments. These factors were partially offset by variations associated with the timing of the collections of gas cost under the Utility’s PGA Clause and increased cash paid for income taxes.

Net cash provided by investing activities for the six months ended March 31, 2008 was $55.5 million compared with net cash used in investing activities of $27.8 million for the six months ended March 31, 2007. The variation is primarily attributable to the proceeds from the sale of SM&P recorded this year.

Net cash used in financing activities was $93.5 million for the six months ended March 31, 2008 compared with $101.5 million for the six months ended March 31, 2007. The variation primarily reflects a decrease in net repayments of short-term debt, partially offset by the maturity of long-term debt this year.


LIQUIDITY AND CAPITAL RESOURCES

As indicated above, the Company’s short-term borrowing requirements typically peak during the colder months. These short-term cash requirements have traditionally been met through the sale of commercial paper supported by lines of credit with banks. Laclede Gas has a line of credit in place of $320 million. During the second quarter, the expiration of this line was extended one year to December 2011 from December 2010. In November 2007, the Utility established a

 
31
 
 

seasonal line of credit of $40 million, which expired in March 2008. The Utility had short-term borrowings aggregating to a maximum of $298.7 million at any one time during the second quarter. Short-term borrowings outstanding at March 31, 2008 were $171.7 million, at a weighted average interest rate of 3.1% per annum. Based on short-term borrowings at March 31, 2008, a change in interest rates of 100 basis points would increase or decrease pre-tax earnings and cash flows by approximately $1.7 million on an annual basis. Portions of such increases or decreases may be offset through the application of PGA carrying costs.

Laclede Gas’ lines of credit include covenants limiting total debt, including short-term debt, to no more than 70% of total capitalization and requiring earnings before interest, taxes, depreciation and amortization (EBITDA) to be at least 2.25 times interest expense. On March 31, 2008, total debt was 56% of total capitalization. For the twelve months ended March 31, 2008, EBITDA was 3.67 times interest expense.

Laclede Gas has on file with the Securities and Exchange Commission (SEC) an effective shelf registration on Form S-3 for issuance of $350 million of securities. The full amount of this shelf registration remains available to Laclede Gas at this time. The Utility has authority from the MoPSC to issue up to $500 million in first mortgage bonds, unsecured debt, and equity securities. In February 2008, pursuant to this authority, the Utility sold 28 shares of its common stock to Laclede Group for $1.0 million, leaving $494.2 million remaining under this authorization as of the date of this filing. The amount, timing and type of additional financing to be issued will depend on cash requirements and market conditions.

On November 1, 2007, Laclede Gas paid at maturity $40 million principal amount of 7 1/2% First Mortgage Bonds. This maturity was funded through short-term borrowings. At March 31, 2008, Laclede Gas had fixed-rate long-term debt totaling $310 million. While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if Laclede Gas were to reacquire any of these issues in the open market prior to maturity.

On April 1, 2008, Laclede Group announced the redemption in full of its $46.4 million Debentures on May 5, 2008 (redemption date), which also triggers the redemption of all of the Trust common and preferred securities on the redemption date. Interest on the Debentures and distributions on the Trust securities will cease to accrue on and after the redemption date. Upon redemption, Laclede Group anticipates recognizing a pre-tax loss of approximately $1.3 million attributable to unamortized debt issuance costs. A portion of the proceeds received from the sale of SM&P will be used to fund the redemption.

Laclede Group has on file a shelf registration on Form S-3 with the SEC that allows for the issuance of equity securities, other than preferred stock, and debt securities. Of the $500 million of securities originally registered under this Form S-3, $362.4 million remain registered and unissued as of March 31, 2008. The amount, timing and type of additional financing to be issued under this shelf registration will depend on cash requirements and market conditions.

Short-term cash requirements outside of Laclede Gas have generally been met with internally-generated funds. However, Laclede Group has $50 million in working capital lines of credit, expiring in August 2008, to meet short-term liquidity needs of its subsidiaries. These lines of credit have covenants limiting the total debt of the consolidated Laclede Group to no more that 70% of the Company’s total capitalization, giving a 50% debt weighting to the subordinated debt issued to an unconsolidated affiliated trust. This ratio stood at 50% on March 31, 2008. These lines have been used to provide letters of credit on behalf of SM&P, and to provide for seasonal funding needs of the various subsidiaries from time to time. Just prior to the SM&P sale, the letters of credit provided on behalf of SM&P totaled $2.8 million. Such letters have been released and extinguished. There were no borrowings under Laclede Group’s lines during the quarter.

Laclede Gas has several operating leases for the rental of vehicles that contain provisions requiring Laclede Gas to guarantee certain amounts related to the residual value of the leased property. These leases have various terms, the longest of which extends through 2014. At March 31, 2008, the maximum guarantees under these leases are $1.7 million. However, the Utility estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At March 31, 2008, the carrying value of the liability recognized for these guarantees was $0.3 million.

SM&P had several operating leases, the aggregate annual cost of which was $8.2 million, consisting primarily of 12-month operating leases, with renewal options, for vehicles used in its business. Laclede Group previously had parental guarantees of certain of those vehicle leases but was released from those guarantees on or before March 31, 2008, concurrent with the sale of SM&P.

 
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Laclede Group had guarantees totaling $50.0 million for performance and payment of certain wholesale gas supply purchases by LER, as of March 31, 2008. Since that date, total guarantees issued by Laclede Group on behalf of LER decreased by $1.0 million, bringing the total to $49.0 million in guarantees outstanding at April 23, 2008. No amounts have been recorded for these guarantees in the financial statements.

Utility capital expenditures were $26.4 million for the six months ended March 31, 2008, compared with $26.1 million for the same period last year. Non-utility capital expenditures were $1.3 million for the six months ended March 31, 2008, compared with $1.1 million for the same period last year.

Consolidated capitalization at March 31, 2008, excluding current obligations of preferred stock, consisted of 57.5% Laclede Group common stock equity, 0.1% Laclede Gas preferred stock equity, 5.5% long-term debt to unconsolidated affiliate trust, and 36.9% Laclede Gas long-term debt.

It is management’s view that the Company has adequate access to capital markets and will have sufficient capital resources, both internal and external, to meet anticipated capital requirements.

The seasonal nature of Laclede Gas’ sales affects the comparison of certain balance sheet items at March 31, 2008 and at September 30, 2007, such as Accounts Receivable - Net, Gas Stored Underground, Notes Payable, Accounts Payable, Regulatory Assets and Regulatory Liabilities, and Delayed and Advance Customer Billings. The Consolidated Balance Sheet at March 31, 2007 is presented to facilitate comparison of these items with the corresponding interim period of the preceding fiscal year.


CONTRACTUAL OBLIGATIONS

As of March 31, 2008, Laclede Group had contractual obligations with payments due as summarized below (in millions):

   
Payments due by period
 
       
Remaining
         
Fiscal Years
 
 
Contractual Obligations
 
Total
 
Fiscal Year
2008
 
Fiscal Years
2009-2010
 
Fiscal Years
2011-2012
 
2013 and
thereafter
 
Principal Payments on Long-Term Debt (a)
 
$
356.4
 
$
 
$
 
$
25.0
 
$
331.4
 
Interest Payments on Long-Term Debt (a)
   
479.4
   
11.5
   
46.2
   
43.7
   
378.0
 
Operating Leases (b)
   
12.0
   
2.6
   
7.4
   
2.0
   
 
Purchase Obligations – Natural Gas (c)
   
2,328.6
   
526.3
   
1,195.7
   
497.9
   
108.7
 
Purchase Obligations – Other (d)
   
108.6
   
10.5
   
18.7
   
16.3
   
63.1
 
Total (e)
 
$
3,285.0
 
$
550.9
 
$
1,268.0
 
$
584.9
 
$
881.2
 

(a)
On April 1, 2008, Laclede Group announced that it would redeem its $46.4 million aggregate principal amount of 7.70% debentures held by Laclede Capital Trust I on May 5, 2008. Interest will cease to accrue on or after this date. The table above reflects obligations at March 31, 2008 and has not been adjusted for this announcement. Specifically, the table reflects principal payments of $46.4 million in the Fiscal Years 2013 and thereafter column and interest payments of $1.8 million, $7.1 million, $7.1 million, and $72.3 million in the Remaining Fiscal Year 2008, Fiscal Years 2009-2010, Fiscal Years 2011-2012, and Fiscal Years 2013 and thereafter columns, respectively. For further details, see Note 10, Subsequent Event, of the Notes to the Consolidated Financial Statements.
(b)
Operating lease obligations are primarily for office space, vehicles, and power operated equipment in the gas distribution segment. Additional payments will be incurred if renewal options are exercised under the provisions of certain agreements.
(c)
These purchase obligations represent the minimum payments required under existing natural gas transportation and storage contracts and natural gas supply agreements in the utility gas distribution and non-regulated gas marketing segments. These amounts reflect fixed obligations as well as obligations to purchase natural gas at future market prices, calculated using March 31, 2008 New York Mercantile Exchange futures prices. Laclede Gas recovers the costs related to its purchases, transportation, and storage of natural gas through the operation of its Purchased Gas Adjustment Clause, subject to prudence review; however, variations in the timing of collections of gas costs from customers affect short-term cash requirements. Additional contractual commitments are generally entered into prior to or during the heating season.


 
33
 
 


(d)
These purchase obligations reflect miscellaneous agreements for the purchase of materials and the procurement of services necessary for normal operations.
(e)
The categories of Capital Leases and Other Long-Term liabilities have been excluded from the table above because there are no applicable amounts of contractual obligations under these categories. Also, commitments related to pension and postretirement benefit plans have been excluded from the table above. The Company expects to make contributions to its qualified, trusteed pension plans totaling $0.6 million during the remainder of fiscal year 2008. Laclede Gas anticipates a $0.2 million contribution relative to its non-qualified pension plans during the remainder of fiscal year 2008. With regard to the postretirement benefits, the Company anticipates Laclede Gas will contribute $4.1 million to the qualified trusts and $0.2 million directly to participants from Laclede Gas’ funds during the remainder of fiscal year 2008. For further discussion of the Company’s pension and postretirement benefit plans, refer to Note 4, Pension Plans and Other Postretirement Benefits, of the Notes to Consolidated Financial Statements.


MARKET RISK

Laclede Gas adopted a risk management policy that provides for the purchase of natural gas financial instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. This policy prohibits speculation. Costs and cost reductions, including carrying costs, associated with the Utility’s use of natural gas financial instruments are allowed to be passed on to the Utility’s customers through the operation of its PGA Clause, through which the MoPSC allows the Utility to recover gas supply costs. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these financial instruments. At March 31, 2008, the Utility held 10.6 million MMBtu of futures contracts at an average price of $7.78 per MMBtu. Additionally, approximately 10.4 million MMBtu of other price risk mitigation was in place through the use of option-based strategies. These positions have various expiration dates, the longest of which extends through March 2009.

In the course of its business, Laclede Group’s non-regulated gas marketing affiliate, LER, enters into fixed price commitments associated with the purchase or sale of natural gas. As part of LER’s risk management policy, LER manages the price risk associated with these commitments by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of exchange-traded futures contracts to lock in margins. At March 31, 2008, LER’s unmatched positions are not material to Laclede Group’s financial position or results of operations.


ENVIRONMENTAL MATTERS

Laclede Gas owns and operates natural gas distribution, transmission and storage facilities, the operations of which are subject to various environmental laws, regulations and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Company’s or Laclede Gas’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas may be required to incur additional costs. For information relative to environmental matters, see Note 14 to the Consolidated Financial Statements included in the Company’s Form 10-K for the fiscal year ended September 30, 2007. There have been no significant changes relative to environmental matters during the six months ended March 31, 2008.


OFF-BALANCE SHEET ARRANGEMENTS

Laclede Group has no off-balance sheet arrangements.


Laclede Gas Company’s Management’s Discussion and Analysis of Financial Condition is included in Exhibit 99.1 of this report.


 
34
 
 

Item 3. Quantitative and Qualitative Disclosures About Market Risk

For this discussion, see the “Market Risk” subsection in Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations, page 34 of this report.

Item 4. Controls and Procedures

As of the end of the period covered by this report, we carried out an evaluation, under the supervision and with participation of our management, including our Chief Executive Officer and Chief Financial Officer, of the effectiveness of the design and operation of our disclosure controls and procedures pursuant to Rule 13a-15e and Rule 15d-15e under the Securities Exchange Act of 1934, as amended. Based upon that evaluation, the Chief Executive Officer and Chief Financial Officer concluded that our disclosure controls and procedures are effective.

There have been no changes in our internal control over financial reporting that occurred during our second fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.





 
35
 
 

PART II. OTHER INFORMATION

Item 1. Legal Proceedings

For a description of environmental matters and legal proceedings, see Note 14 to the Consolidated Financial Statements included in the Company’s Form 10-K for the fiscal year ended September 30, 2007. For a description of pending regulatory matters of Laclede Gas, see Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Regulatory Matters, on page 29 of this report.

Laclede Group and its subsidiaries are involved in litigation, claims and investigations arising in the normal course of business. While the results of such litigation cannot be predicted with certainty, management, after discussion with counsel, believes that the final outcome will not have a material adverse effect on the consolidated financial position or results of operations of the Company.

Item 2. Unregistered Sales of Equity Securities and Use of Proceeds

On February 14, 2008, the Board of Directors of Laclede Gas approved the sale of 28 shares of Laclede Gas common stock to Laclede Group. The proceeds from the sale, totaling $1.0 million, were used to reduce short-term borrowings. Exemption from registration was claimed under Section 4(2) of the Securities Act of 1933.

Item 4. Submission of Matters to a Vote of Security Holders

The annual meeting of The Laclede Group was held on January 31, 2008. Below are the matters voted upon at the meeting.

The following individuals were elected to the Board of Directors of The Laclede Group:

Director
Votes in Favor
Votes Against
Edward L. Glotzbach
18,104,118
305,818
W. Stephen Maritz
18,102,274
307,662
John P. Stupp, Jr.
18,099,128
310,808

The other matter received the following votes:

Proposal
Votes In Favor
Votes Against
Abstain
Ratify appointment of Deloitte & Touche LLP as independent auditors for fiscal year 2008
 
18,167,079
 
154,173
 
88,684

Item 6. Exhibits

(a)
See Exhibit Index










 
36
 
 


SIGNATURES
 
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.
 
     
The Laclede Group, Inc.
       
 Dated:
 
April 23, 2008
 
By: 
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Chief Financial Officer
         
(Authorized Signatory and Chief Financial Officer)







 
37
 
 


SIGNATURES
 
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrants have duly caused this report to be signed on their behalf by the undersigned thereunto duly authorized.
 
     
Laclede Gas Company
       
 Dated:
 
April 23, 2008
 
By: 
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Senior Vice President and
         
Chief Financial Officer
         
(Authorized Signatory and Chief Financial Officer)






 
38
 
 



INDEX TO EXHIBITS


Exhibit No.
   
     
10.1
-
Second amendment dated February 8, 2008 to syndicated loan agreement of Laclede Gas Company dated September 10, 2004 and first amended December 23, 2005.
     
10.2
-
Restricted Stock Unit Award Agreement with Douglas H. Yaeger dated February 14, 2008.
     
10.3
-
Stock Purchase Agreement between the Company and Stripe Acquisition, Inc. dated February 15, 2008 for the sale of SM&P Utility Resources, Inc.
     
10.4
-
Supplemental Pension Agreement between Laclede Gas Company and Kenneth J. Neises dated March 7, 2008.
     
10.5
-
Amended and Restated Storage Service Agreement between Laclede Gas Company and Centerpoint Energy - Mississippi River Transmission Corporation dated March 18, 2008 for Rate Schedule FSS, Contract #3147.
     
10.6
-
Amended and Restated Transportation Service Agreement between Laclede Gas Company and Centerpoint Energy - Mississippi River Transmission Corporation dated March 18, 2008 for Rate Schedule FTS, Contract #3310.
     
10.7
-
Amended and Restated Transportation Service Agreement between Laclede Gas Company and Centerpoint Energy - Mississippi River Transmission Corporation dated March 18, 2008 for Rate Schedule FTS, Contract #3311.
     
10.8
-
First Amendment to Amended and Restated Revolving Credit Agreement between the Company and US Bank, National Association dated March 31, 2008.
     
12
-
Ratio of Earnings to Fixed Charges.
     
31
-
CEO and CFO Certifications under Exchange Act Rule 13a – 14(a).
     
32
-
CEO and CFO Section 1350 Certifications.
     
99.1
-
Laclede Gas Company - Financial Statements, Notes to Financial Statements, and Management’s Discussion and Analysis of Financial Condition and Results of Operations.
     




 
39
 
 

EX-10.1 2 ex10-1.htm EXHIBIT 10.1 ex10-1.htm

Exhibit 10.1

SECOND AMENDMENT TO LOAN AGREEMENT

THIS SECOND AMENDMENT TO LOAN AGREEMENT (this “Amendment”) is made and entered into as of February 8, 2008, by and between:  LACLEDE GAS COMPANY, a Missouri corporation (“Borrower”); and Banks from time to time party to the Agreement (defined below), including U.S. BANK NATIONAL ASSOCIATION, a national banking association, in its capacity as a Bank and as Administrative Agent under the Agreement (“Administrative Agent”); and has reference to the following facts and circumstances (the “Recitals”):

A.           Borrower, Administrative Agent and certain Banks executed the Amended and Restated Loan Agreement dated as of September 10, 2004 (as amended, the “Agreement”; all capitalized terms used and not otherwise defined in this Amendment shall have the respective meanings ascribed to them in the Agreement as amended by this Amendment).

B.           The Agreement was previously amended as described in the Amendment to Loan Agreement dated as of December 23, 2005; and Borrower, Administrative Agent and Banks desire to further amend the Agreement in the manner hereinafter set forth.

NOW, THEREFORE, in consideration of the premises and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, Borrower, Administrative Agent and Banks hereby agree as follows:

1.           Recitals.  The Recitals are true and correct, and, together with the defined terms set forth herein, are incorporated by this reference.

2.           Amendment to Agreement. The Agreement is amended as follows:

(a)           The definition of “Revolving Credit Period” in Section 1.01 of the Agreement, is deleted and replaced with the following:

Revolving Credit Period shall mean the period commencing on the date of this Agreement and ending on December 31, 2011, or as extended pursuant to Section 2.01(e); provided, however, that the Revolving Credit Period shall end on the date the Revolving Credit Commitment is terminated pursuant to Section 6 or otherwise.”

(b)           The definition of “Non-Consenting Bank” in Section 1.01 of the Agreement is deleted and replaced with the following:

Non-Consenting Bank shall have the meaning ascribed thereto in Section 2.01(e) and each Non-Consenting Bank is set forth on Schedule 1.01A attached hereto and incorporated by reference.”

(c)           Section 4.07 of the Agreement is deleted and replaced with the following:

“4.07  Investment Company Act of 1940; Public Utility Holding Company Act of 1935.  Borrower is not an “investment company” as that term is defined in, and is not otherwise subject to regulation under, the Investment Company Act of 1940, as amended.  Borrower is not (a) a “holding company” as defined in the Public Utility Holding Company Act of 2005, as amended (“PUHCA”), but is a subsidiary of a holding company for which compliance with the accounting, record retention and reporting sections of PUHCA has been waived or (b) subject to regulation under PUHCA, other than as a subsidiary of a holding company under PUHCA.”

(d)           Schedule 1.01 and Schedule 2.02 of the Agreement are deleted and replaced with Schedule 1.01 and Schedule 2.02 attached hereto and incorporated by reference.

(e)           Schedule 1.01A attached hereto and incorporated by reference is added to the Agreement as Schedule 1.01A.

3.           Extension Request.  Borrower, Administrative Agent and Banks acknowledge and agree that:  (a) Borrower submitted an Extension Request to Administrative Agents and Banks to extend the Revolving Credit Period from December 31, 2010 to December 31, 2011; (b) Administrative Agent and all Banks, except for Bank Hapoalim B.M. and First Bank, consented to such Extension Request; (c) the conditions for approval of such Extension Request under Section 2.01(e) of the Agreement have been satisfied; (d) Bank Hapoalim B.M. and First Bank shall no longer be Banks under the Agreement and the Revolving Credit Commitments and Pro Rata Shares of the remaining Banks have been reallocated as described in revised Schedule 1.01 attached hereto; and (e) as a result, the last day of the Revolving Credit Period shall be extended to December 31, 2011 for all remaining Banks.

4.           Costs and Expenses.  Borrower hereby agrees to reimburse Administrative Agent upon demand for all out-of-pocket costs and expenses (including, without limitation, reasonable attorneys’ fees and expenses) incurred by Administrative Agent in the preparation, negotiation and execution of this Amendment and any and all other agreements, documents, instruments and/or certificates relating to the amendment of Borrower’s existing credit facilities with Administrative Agent and Banks.  Borrower further agrees to pay or reimburse Administrative Agent for (a) any stamp or other taxes (excluding income or gross receipts taxes) which may be payable with respect to the execution, delivery, filing and/or recording of any of the Transaction Documents, and (b) the cost of any filings and searches, including, without limitation, Uniform Commercial Code filings and searches.  All of the obligations of Borrower under this paragraph shall survive the payment of Borrower’s Obligations and the termination of the Agreement.

5.           References to this Agreement. All references in the Agreement to “this Agreement” and any other references of similar import shall henceforth mean the Agreement as amended by this Amendment.

6.           Full Force and Effect. Except to the extent specifically amended by this Amendment, all of the terms, provisions, conditions, covenants, representations and warranties contained in the Agreement shall be and remain in full force and effect and the same are hereby ratified and confirmed.

7.           Benefit.  This Amendment shall be binding upon and inure to the benefit of Borrower, Administrative Agent and Banks and their respective successors and assigns, except that Borrower may not assign, transfer or delegate any of its rights or obligations under the Agreement as amended by this Amendment.

8.           Representations and Warranties.  Borrower hereby represents and warrants to Administrative Agent and Banks that:

(a)           the execution, delivery and performance by Borrower of this Amendment are within the corporate powers of Borrower, have been duly authorized by all necessary corporate action and require no action by or in respect of, consent of or filing or recording with, any governmental or regulatory body, instrumentality, authority, agency or official or any other Person;

(b)           the execution, delivery and performance by Borrower of this Amendment do not conflict with, or result in a breach of the terms, conditions or provisions of, or constitute a default under
 
- 2 - -
or result in any violation of, the terms of the Articles of Incorporation or Bylaws of Borrower, any applicable law, rule, regulation, order, writ, judgment or decree of any court or governmental or regulatory body, instrumentality authority, agency or official or any agreement, document or instrument to which Borrower is a party or by which Borrower or any of its property is bound or to which Borrower or any of its property is subject;

(c)           this Amendment has been duly executed and delivered by Borrower and constitutes the legal, valid and binding obligation of Borrower enforceable against Borrower in accordance with its terms, except as such enforceability may be limited by (i) applicable bankruptcy, insolvency or similar laws affecting the enforcement of creditors’ rights generally and (ii) general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law);

(d)           all of the representations and warranties made by Borrower in the Agreement and/or in any of the other Transaction Documents are true and correct in all material respects on and as of the date of this Amendment as if made on and as of the date of this Amendment; and

(e)           as of the date of this Amendment, no Default or Event of Default under or within the meaning of the Agreement has occurred and is continuing.

9.           Release. Borrower hereby unconditionally releases, acquits, waives, and forever discharges Administrative Agent and each Bank and their successors, assigns, directors, officers, agents, employees, representatives and attorneys from any and all liabilities, claims, causes of action or defenses, if any, and for any action taken or for any failure to take any action, existing at any time prior to the execution of this Amendment.

10.           Inconsistency. In the event of any inconsistency or conflict between this Amendment and the Agreement, the terms, provisions and conditions contained in this Amendment shall govern and control.

11.           Missouri Law. This Amendment shall be governed by and construed in accordance with the substantive laws of the State of Missouri (without reference to conflict of law principles).

12.           Notice Required by Section 432.047 R.S. Mo.  ORAL AGREEMENTS OR COMMITMENTS TO LOAN MONEY, EXTEND CREDIT OR TO FORBEAR FROM ENFORCING REPAYMENT OF A DEBT INCLUDING PROMISES TO EXTEND OR RENEW SUCH DEBT ARE NOT ENFORCEABLE, REGARDLESS OF THE LEGAL THEORY UPON WHICH IT IS BASED THAT IS IN ANY WAY RELATED TO THE CREDIT AGREEMENT.  TO PROTECT YOU (BORROWER(S)) AND US (CREDITOR) FROM MISUNDERSTANDING OR DISAPPOINTMENT, ANY AGREEMENTS WE REACH COVERING SUCH MATTERS ARE CONTAINED IN THIS WRITING, WHICH IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN US, EXCEPT AS WE MAY LATER AGREE IN WRITING TO MODIFY IT.

13.           Conditions Precedent. Notwithstanding any provision contained in this Amendment to the contrary, this Amendment shall not be effective unless and until Administrative Agent shall have received the following, all in form and substance acceptable to Administrative Agent:

(a)           this Amendment, duly executed by Borrower and Banks;

- 3 - -
(b)           a copy of resolutions of the Board of Directors of Borrower, duly adopted, which authorize the execution, delivery and performance of this Amendment, certified by the Secretary of Borrower;

(c)           an incumbency certificate, executed by the Secretary of Borrower, which shall identify by name and title and bear the signature(s) of the officer(s) of Borrower executing this Amendment and the new Notes;

(d)           a certificate of good standing for Borrower, issued by the Secretary of State of Missouri, or other proof of current good standing acceptable to Administrative Agent;

(e)           payment by Borrower of the applicable arrangement, upfront and other fees as described in the fee letter provided by Administrative Agent to Borrower in connection with this Amendment; and

(f)           such other documents and information as reasonably requested by Administrative Agent and Banks.

IN WITNESS WHEREOF, Borrower, Administrative Agent and Banks have executed this Amendment as of the day and year first above written.




(SIGNATURES ON FOLLOWING PAGES)



 
 
- 4 - -
 
 


SIGNATURE PAGE-BORROWER
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
Borrower:
     
 
LACLEDE GAS COMPANY
     
 
By:
/s/ Lynn D. Rawlings
   
Lynn D. Rawlings, Treasurer and Assistant Secretary






 

 

 
 
 
 
- 5 - -
 
 


SIGNATURE PAGE- ADMINISTRATIVE AGENT AND U.S. BANK
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
U.S. BANK NATIONAL ASSOCIATION,
 
as Administrative Agent
     
 
By:
/s/ John Eyerman
     
 
Name:
John Eyerman
     
 
Title:
Banking Officer
     
     
     
     
 
U.S. BANK NATIONAL ASSOCIATION, as a Bank
     
 
By:
/s/ John Eyerman
     
 
Name:
John Eyerman
     
 
Title:
Banking Officer
     








 

 

 
 
 
 
 
- 6 - -
 
 




SIGNATURE PAGE- SOUTHWEST BANK OF ST. LOUIS
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
SOUTHWEST BANK OF ST. LOUIS
     
 
By:
/s/ Mark Sauerwein
     
 
Name:
Mark Sauerwein
     
 
Title:
SVP
     
     





 

 

 
 
 
 
 
- 7 - -
 
 



SIGNATURE PAGE- COMERICA BANK
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
COMERICA BANK
     
 
By:
/s/ Mark J. Leveille
     
 
Name:
Mark J. Leveille
     
 
Title:
Vice President
     
     




 

 

 
 
 
 
 
- 8 - -
 
 



SIGNATURE PAGE- THE BANK OF TOKYO-MITSUBISHI UFJ, LTD.
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
THE BANK OF TOKYO-MITSUBISHI UFJ, LTD.,
    the successor-by-merger to UFJ Bank Limited
     
 
By:
/s/ Alan Reiter
     
 
Name:
Alan Reiter
     
 
Title:
Authorized Signatory
     
     




 

 

 
 
 
 
 
- 9 - -
 
 


SIGNATURE PAGE- FIFTH THIRD BANK
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
FIFTH THIRD BANK
     
 
By:
/s/ Robert M. Sander
     
 
Name:
Robert M. Sander
     
 
Title:
Vice President
     
     




 

 

 
 
 
 
 
- 10 - -
 
 


SIGNATURE PAGE- THE BANK OF NEW YORK
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
THE BANK OF NEW YORK
     
 
By:
/s/ Cynthia D. Howells
     
 
Name:
Cynthia D. Howells
     
 
Title:
Vice President
     
     




 

 

 
 
 
 
 
- 11 - -
 
 


SIGNATURE PAGE- NATIONAL CITY BANK
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
NATIONAL CITY BANK
     
 
By:
/s/ Stephen Sainz
     
 
Name:
Stephen Sainz
     
 
Title:
Vice President
     
     




 

 

 
 
 
 
 
- 12 - -
 
 


SIGNATURE PAGE- REGIONS BANK
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
REGIONS BANK
     
 
By:
/s/ Steven A. Linton
     
 
Name:
Steven A. Linton
     
 
Title:
Senior Vice President
     
     



 

 

 
 
 
 
 
- 13 - -
 
 


SIGNATURE PAGE- COMMERCE BANK, NATIONAL ASSOCIATION
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
COMMERCE BANK, NATIONAL ASSOCIATION
     
 
By:
/s/ Douglas P. Best
     
 
Name:
Douglas P. Best
     
 
Title:
Vice President
     
     






 

 

 
 
 
 
 
- 14 - -
 
 


SIGNATURE PAGE- FIRST NATIONAL BANK OF ST. LOUIS
SECOND AMENDMENT TO LOAN AGREEMENT
   
     
     
 
FIRST NATIONAL BANK OF ST. LOUIS
     
 
By:
/s/ George W. Fitzwater
     
 
Name:
George W. Fitzwater
     
 
Title:
Senior Vice President & CFO
     
     





 

 

 
 
 
 
 
- 15 - -
 
 


SCHEDULE 1.01
     
Revolving Credit Commitments and Pro Rata Shares
     
Bank
Revolving Credit Commitment
Pro Rata Share
     
U.S. Bank National Association
$56,000,000
17.500000000000%
Southwest Bank of St. Louis
$36,800,000
11.500000000000%
Comerica Bank
$36,600,000
11.437500000000%
The Bank Of Tokyo-Mitsubishi UFJ, Ltd.
$35,000,000
10.937500000000%
Fifth Third Bank
$30,100,000
9.406250000000%
The Bank of New York
$30,000,000
9.375000000000%
National City Bank
$30,000,000
9.375000000000%
Regions Bank
$30,000,000
9.375000000000%
Commerce Bank, National Association
$25,000,000
7.812500000000%
First National Bank of St. Louis
$10,500,000
3.281250000000%
     
TOTAL:
$320,000,000
100.000000000000%
     





 
 
 
 

SCHEDULE 1.01A

Non-Consenting Banks


Bank Hapoalim B.M. and First Bank (no longer Banks as of effective date of Second Amendment to Loan Agreement)




 
 
 
 

SCHEDULE 2.02

Authorized Individuals


Douglas H. Yaeger, Chairman, President and Chief Executive Officer

Mark D. Waltermire, Chief Financial Officer

Lynn D. Rawlings, Treasurer and Assistant Secretary

Delfina Myers, Authorized Individual



 
 
 
 

EX-10.2 3 ex10-2.htm EXHIBIT 10.2 ex10-2.htm

Exhibit 10.2

The Laclede Group

2006 Equity Incentive Plan
Restricted Stock Unit Award Agreement


THIS RESTRICTED STOCK UNIT AWARD AGREEMENT is made as of this 14th day of February 2008, between The Laclede Group, Inc. (the “Company”) and Douglas H. Yaeger (the “Participant”).  References in this Agreement to “Company” include Subsidiaries and any entity that succeeds to all or substantially all of the business of The Laclede Group, Inc.

Pursuant to the terms of the Company’s 2006 Equity Incentive Plan, as approved by shareholders in January 2006, (the “Plan”), the award under this Agreement is being made as a special grant of restricted stock units of the Company authorized by the Board of Directors and the Board’s Compensation Committee (“Committee”), subject to the Participant’s acceptance of the terms, conditions and restrictions applicable to the restricted stock units set forth in this Agreement.

NOW, THEREFORE, in consideration of the mutual covenants set forth in this Agreement, the parties hereto hereby agree as follows:

1.           Award of Restricted Stock Units.  Pursuant and subject to the terms and conditions set forth herein and in the Plan, the Company awards to the Participant Fifteen Thousand (15,000) restricted stock units (the “Units”), subject to the terms, conditions and restrictions described in this Agreement and in the Plan (the “Award”).

2.           Award Date.  The Award Date of the Units in this Award is February 14, 2008.

3.           Incorporation of Plan.  All terms, conditions and restrictions of the Plan are incorporated herein and made part hereof as if stated herein.  If there is any conflict between the terms and conditions of the Plan and this Agreement, the terms and conditions of the Plan, as interpreted by the plan administrator, shall govern.  All capitalized terms used herein, but not otherwise defined, shall have the meaning given to such terms in the Plan.

4.           Restrictions and Conditions.  The Units are being awarded to Participant subject to the transfer and forfeiture conditions set forth below that shall lapse, if at all, as described in Section 5.

5.           Lapse of Restrictions.  The Participant accepts this Award and agrees that the restrictions relative to the Units shall lapse and Participant shall vest in all Units on December 1, 2011 (the “Vesting Date”) provided Participant has not left the employment of the Company for any reason other than a termination by the Company without Cause
 
1
prior to such Vesting Date.  If the Participant’s employment is terminated by the Company without Cause prior to the Vesting Date, the restrictions shall lapse as to all Units upon the date of such termination.  Participant acknowledges, however, that Participant shall forfeit for no consideration all Units under this Award if Participant leaves the employ of the Company other than by termination by the Company without Cause.

Notwithstanding anything in the Plan to the contrary, restrictions on the Units shall not lapse solely upon the occurrence of a Change in Control.

6.           Dividends and Other Shareholder Rights.  Participant shall have no rights as a shareholder of the Company in respect of the Units including the right to vote and to receive cash dividends or dividend equivalents and other distributions until delivery of the shares of Common Stock in settlement of the Units.

7.           Adjustments.  In the event of any Event (as defined in Section 13.1 of the Plan) that the plan administrator determines should result in the adjustment of Common Stock to prevent dilution or enlargement of the benefits intended to be granted hereunder, the plan administrator shall adjust the Award as it deems appropriate to prevent such dilution or enlargement.

8.           Delivery of Certificates or Equivalent.  Upon the lapse of restrictions applicable to the Units, the Company shall deliver to the Participant a certificate or evidence of direct registration of a number of shares of Common Stock equal to the number of Units upon which such restrictions shall have lapsed.  No fractional shares shall be issued.

9.           No Right to Continued Employment.  Nothing in this Agreement shall confer on the Participant any right to continuance of employment by the Company or a subsidiary nor shall it interfere in any way with the right of Participant’s employer to terminate Participant’s employment at any time.

10.           Tax Withholding.  The Company is entitled to withhold applicable taxes for the respective tax jurisdictions attributable to this Award or any payment made in connection with the Units.  Participant may satisfy any withholding obligation by electing to have the plan administrator retain shares of Common Stock deliverable in connection with the Units having a Fair Market Value on the date the restrictions lapse as provided in Section 5 equal to the amount to be withheld.

11.           Confidential Information and Restrictions on Soliciting Employees. Notwithstanding any provision of this Agreement to the contrary, the Participant shall pay to the Company the Fair Market Value of the shares of Common Stock attributable to the Units that vest under this Award, if, during the period beginning on the Award Date hereof and ending 12 months following the date the Participant’s employment with the Company terminates, the Participant: (1) discloses Confidential Information, as defined below, to any person not employed by the Company or not engaged to render services to
 
2
the Company; or (2) Solicits Employees, as defined below.  Fair Market Value shall be calculated on the date of the first violation of this Section 11.

For purposes of this Section 11, “Confidential Information” means information concerning the Company and the business that is not generally known outside the Company, and includes (A) trade secrets; (B) intellectual property; (C) methods of operation and processes; (D) information regarding present and/or future products, developments, processes and systems; (E) information on customers or potential customers, including customers’ names, sales records, prices, and other terms of sales and cost information; (F) personnel data; (G) business plans, marketing plans, financial data and projections; and (H) information received in confidence from third parties. This provision shall not preclude the Participant from use or disclosure of information known generally to the public or of information not considered confidential by persons engaged in the business conducted by the Company or subsidiary or from disclosure required by law or court order.

“Solicits Employees” means the Participant’s direct or indirect hire, solicit to hire, or attempt to induce any employee of the Company or a subsidiary (who is an employee of the Company or a subsidiary as of the time of such hire or solicitation or attempt to hire) or any former employee of the Company or a subsidiary (who was employed by the Company or a subsidiary within the 12-month period immediately preceding the date of such hire or solicitation or attempt to hire) to leave the employment of the Company or a subsidiary.

12.           Integration.  This Agreement, and the other documents referred to herein or delivered pursuant hereto that form a part hereof, contain the entire understanding of the parties with respect to its subject matter.  There are no restrictions, agreements, promises, representations, warranties, covenants or undertakings with respect to the subject matter hereof other than those expressly set forth herein.  This Agreement, including without limitation the Plan, supersedes all prior agreements and understandings between the parties with respect to its subject matter and may only be amended by mutual written consent of the parties.

13.           Governing Law.  This Agreement shall be governed by and construed and enforced in accordance with the laws of the State of Missouri, without regard to the provisions governing conflict of laws.

14.           Compliance with Laws and Regulations.  The obligation of the Company to deliver shares of Common Stock hereunder shall be subject to all applicable federal and state laws, rules and regulations and to such approvals by any government or regulatory agency as may be required.

15.           Non-Transferability.  The Units shall not be transferable by Participant and may not be, sold, assigned, disposed of, or pledged or hypothecated as collateral for a loan or as security for performance of any obligation or for any other purpose until after the restrictions have lapsed as provided in Section 5.

3
Further, for a period of 12 months after the Vesting Date, Participant shall not transfer, assign, sell, dispose of, pledge or hypothecate as collateral for a loan or as security for performance of any obligation or for any other purpose shares of Common Stock delivered to Participant upon the lapse of restrictions on the Vesting Date.  The parties agree that this restriction on transfer of shares of Common Stock shall not restrict Participant’s ability to elect to have the plan administrator retain shares for tax withholding purposes as provided in Section 10.

16.           Participant Acknowledgment.  By accepting this Award, the Participant acknowledges receipt of a copy of the Plan, and acknowledges that all decisions, determinations and interpretations of the plan administrator in respect of the Plan and this Agreement shall be final and conclusive.

In addition, the Participant expressly acknowledges that violation by the Participant of Section 11 of this Agreement will obligate the Participant to pay to the Company the Fair Market Value of Common Stock relative to the Units that become vested pursuant to Section 5.

IN WITNESS WHEREOF, the parties hereto have executed this Agreement as of the day first written above.



 
THE LACLEDE GROUP, INC.
     
 
By:
 
   
M. D. Waltermire
 
Title:
Chief Financial Officer
     
     
   
Douglas H. Yaeger
     




 
4
 
 

EX-10.3 4 ex10-3.htm EXHIBIT 10.3 ex10-3.htm Exhibit 10.3


 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 
 

 
STOCK PURCHASE AGREEMENT
 
Between
 
THE LACLEDE GROUP, INC.
 
and
 
STRIPE ACQUISITION, INC.
 

 
February 15, 2008
 

 
 
 
 
 
    TABLE OF CONTENTS  
      Page 
       
 
DEFINITIONS
1
         
2.
 
PURCHASE AND SALE OF SM&P SHARES
7
         
   
(a)
Basic Transaction
7
         
   
(b)
Purchase Price
7
         
   
(c)
Purchase Price Adjustment
8
         
   
(d)
The Closing
10
         
   
(e)
Deliveries at the Closing
11
         
3.
 
REPRESENTATIONS AND WARRANTIES CONCERNING THE
 
   
TRANSACTION
11
         
   
(a)
Representations and Warranties of the Seller
11
         
   
(b)
Representations and Warranties of the Buyer
12
         
4.
 
REPRESENTATIONS AND WARRANTIES OF THE SELLER CONCERNING
   
SM&P
14
         
   
(a)
Organization, Qualification and Corporate Power
14
         
   
(b)
Capitalization
14
         
   
(c)
Noncontravention
15
         
   
(d)
Financial Statements
15
         
   
(e)
Title to Personal Property
15
         
   
(f)
Legal Compliance
15
         
   
(g)
Contracts
16
         
   
(h)
Litigation
16
         
   
(i)
Environmental Matters
17
         
   
(j)
Insurance
18
         
   
(k)
Employee Relations
18
         
   
(l)
Taxes
18
         
   
(m)
Events After September 30, 2007
19
         
   
(n)
Customers
20
         
   
(o)
Condition of Personal Property
20
         
   
(p)
Real Property
20
         
   
(q)
Transactions with Affiliates
21
         
   
(r)
Employee Benefits
21
 
- i -
 

      TABLE OF CONTENTS  
       (continued)  
     
 
Page 
         
   
(s)
Sufficiency of Assets
22
         
   
(t)
Accounts Receivable
22
         
   
(u)
Employees
23
         
   
(v)
Intellectual Property
23
         
   
(w)
Undisclosed Liabilities
24
         
5.
 
PRE-CLOSING COVENANTS
25
         
   
(a)
General
25
         
   
(b)
Notices and Consents
25
         
   
(c)
Operations of Business
25
         
   
(d)
Full Access
27
         
   
(e)
Notice of Developments
27
         
   
(f)
Parent Guaranties
28
         
   
(g)
Termination of Affiliate Transactions
28
         
   
(h)
Exclusivity
28
         
6.
 
POST-CLOSING COVENANTS
28
         
   
(a)
General
28
         
   
(b)
Litigation Support
28
         
   
(c)
Transition
29
         
   
(d)
Access to Information and Cooperation
29
         
   
(e)
Noncompete
29
         
   
(f)
Employee Matters
30
         
7.
 
CONDITIONS TO OBLIGATION TO CLOSE
31
         
   
(a)
Conditions to Obligation of the Buyer
31
         
   
(b)
Conditions to Obligation of the Seller
33
         
8.
 
REMEDIES FOR BREACHES OF THIS AGREEMENT
33
         
   
(a)
Survival of Representations and Warranties
33
         
   
(b)
Indemnification Provisions for Benefit of the Buyer
34
         
   
(c)
Indemnification Provisions for Benefit of the Seller
34
         
   
(d)
Matters Involving Third Parties
34
         
   
(e)
No Contribution
35
 
- ii -
 
 
 
      TABLE OF CONTENTS  
       (continued)  
        Page 
         
   
(f)
Exclusive Remedies
35
         
9.
 
TAX MATTERS
35
         
   
(a)
Scope of Tax Indemnity Provisions
35
         
   
(b)
Allocation of Liability for Taxes
35
         
   
(c)
Proration of Taxes
36
         
   
(d)
Refunds of Taxes; Amended Returns; Carryovers
37
         
   
(e)
Preparation and Filing of Tax Returns
38
         
   
(f)
Tax Controversies; Assistance and Cooperation
39
         
   
(g)
Termination of Tax Allocation Agreements
41
         
   
(h)
Indemnification for Post-Closing Transactions
41
         
   
(i)
Post-Closing Transactions Not in the Ordinary Course
41
         
   
(j)
Survival
41
         
   
(k)
Conflicts
41
         
10.
 
TERMINATION
41
         
   
(a)
Termination of Agreement
41
         
   
(b)
Effect of Termination
42
         
11.
 
MISCELLANEOUS
42
         
   
(a)
Press Releases and Public Announcements
42
         
   
(b)
No Third Party Beneficiaries
42
         
   
(c)
Entire Agreement
42
         
   
(d)
Succession and Assignment
43
         
   
(e)
Counterparts; Facsimile
43
         
   
(f)
Headings
43
         
   
(g)
Notices
43
         
   
(h)
Governing Law
44
         
   
(i)
Amendments and Waivers
44
         
   
(j)
Severability
44
         
   
(k)
Expenses
44
         
   
(l)
Construction
44
 
 
- iii -
 
 



STOCK PURCHASE AGREEMENT
 
THIS STOCK PURCHASE AGREEMENT (this “Agreement”) is entered into as of February 15, 2008, between The Laclede Group, Inc., a Missouri corporation (the “Seller”), and Stripe Acquisition, Inc., a Delaware corporation (the “Buyer”).  The Buyer and the Seller are herein referred to individually as “Party” and collectively as the “Parties.”
 
The Seller owns all of the issued and outstanding stock of SM&P Utility Resources, Inc., an Indiana corporation (“SM&P”).  This Agreement contemplates a transaction in which the Buyer will purchase from the Seller, and the Seller will sell to the Buyer, all of the outstanding capital stock of SM&P for the consideration described in Section 2(b).
 
Now, therefore, in consideration of the premises and the mutual promises herein made, and in consideration of the representations, warranties and covenants herein contained, the Parties agree as follows.
 
1.           DEFINITIONS.
 
Adverse Consequences” means all actions, suits, proceedings, hearings, investigations, charges, complaints, claims, demands, injunctions, judgments, orders, decrees, rulings, damages, dues, penalties, fines, costs, reasonable amounts paid in settlement, liabilities, obligations, taxes, liens, losses, expenses and fees, including court costs and reasonable attorneys' fees and expenses, as adjusted for tax benefits actually realized and insurance coverage actually obtained (net of any associated increased costs resulting from any insurance recoveries made in respect of any Adverse Consequences), but not including consequential damages.
 
Affiliate” of a Person means another Person that controls, is controlled by, or is under common control with such first Person.
 
Affiliated Group” means any affiliated group within the meaning of Code Section 1504.
 
Agreement” has the meaning set forth in the first paragraph of this Agreement.
 
Applicable Tax Law” means any law of any nation, state, region, province, locality, municipality or other jurisdiction relating to Taxes, including regulations and other official pronouncements of any governmental entity or political subdivision of such jurisdiction charged with interpreting such laws.
 
Buyer” has the meaning set forth in the first paragraph of this Agreement.
 
Buyer Benefit Plan” means any Employee Benefit Plan maintained or contributed to by the Buyer.
 
Cap” has the meaning set forth in Section 8(b)(ii).
 
Claim Deductible” means $25,000.
 

 
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Closing” has the meaning set forth in Section 2(d).
 
Closing Date” has the meaning set forth in Section 2(d).
 
Closing Working Capital” has the meaning set forth in Section 2(c)(iii)(F).
 
Code” means the Internal Revenue Code of 1986, as amended.
 
Confidentiality Agreements” has the meaning set forth in Section 5(d).
 
Confidential Information” has the meaning set forth in Section 6(e)(iii).
 
Debt Financing Commitment” has the meaning set forth in Section 3(b)(vi).
 
Deductible” has the meaning set forth in Section 8(b)(ii).
 
Disclosure Schedule” means the disclosure schedule attached as Annex I to this Agreement.
 
Draft Working Capital Closing Statement” has the meaning set forth in Section 2(c)(iii)(A).
 
Employee Benefit Plan” means any Employee Pension Benefit Plan, any Employee Welfare Benefit Plan and any other executive compensation plan, executive security plan, bonus plan, incentive compensation plan, deferred compensation plan or agreement, employment agreement, consulting agreement, change in control agreement, golden or tin parachute arrangement, employee pension, retirement, profit sharing or savings plan, employee stock purchase, stock option or stock award plan, group life insurance, health, hospitalization, dental and disability plan, severance plan, tuition assistance program, personnel policy (including but not limited to holiday pay, moving expense reimbursement, sick leave, vacation pay or benefit arrangement) or any other fringe benefit arrangement.
 
Employee Pension Benefit Plan” has the meaning set forth in ERISA Section 3(2).
 
Employee Welfare Benefit Plan” has the meaning set forth in ERISA Section 3(1).
 
Environmental Laws” has the meaning set forth in Section 4(i).
 
Equity Financing Commitment” has the meaning set forth in Section 3(b)(vi).
 
ERISA” means the Employee Retirement Income Security Act of 1974, as amended.
 
Estimated Adjusted Purchase Price” has the meaning set forth in Section 2(c)(i).
 
Estimated Working Capital” has the meaning set forth in Section 2(c)(ii).
 
Estimated Working Capital Target” has the meaning set forth in Section 2(c)(ii).
 

 
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Estimated Working Capital Closing Statement” has the meaning set forth in Section 2(c)(ii).
 
Estimated Working Capital Target Closing Statement” has the meaning set forth in Section 2(c)(ii).
 
Final Adjusted Purchase Price has the meaning set forth in Section 2(c)(iii)(G).
 
Financing Commitments” has the meaning set forth in Section 3(b)(vi).
 
Formal IP” has the meaning set forth in Section 4(v)(ii).
 
GAAP” means accounting principles generally accepted in the United States as in effect from time to time.
 
Hazardous Substances” means any substance defined or listed as a hazardous substance, waste or material under the Comprehensive Environmental Response, Compensation, and Liability Act or any comparable state Environmental Law that is applicable and includes petroleum oil and its fractions and petroleum-derived products but does not include natural gas or building materials such as paint and insulation.
 
HSR Act” means the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended, and the rules and regulations promulgated thereunder.
 
Indebtedness means, of any Person, without duplication, (a) indebtedness for borrowed money or indebtedness issued or incurred in substitution or exchange for indebtedness for borrowed money, (b) indebtedness evidenced by any note, bond, debenture, mortgage or other debt instrument or debt security, (c) obligations under any interest rate, currency or other currency hedging agreement, (d) obligations under any performance bond or letter of credit, but only to the extent drawn or called prior to the Closing Date, (e) all capitalized lease obligations as determined under GAAP, (f) guarantees with respect to any indebtedness of any other Person of a type described in clauses (a) through (e) above, (g) for clauses (a) through (f) above, all accrued interest thereon, if any, and any termination fees, prepayment penalties, "breakage" cost or similar payments associated with the repayments of such Indebtedness on the Closing Date.  For the avoidance of doubt, Indebtedness shall not include (a) any obligations under any performance bond or letter of credit to the extent undrawn or uncalled, (b) any Indebtedness included in the calculation of current liabilities in the determination of Working Capital (as determined in accordance with the calculations set forth on Section 2(c) of the Disclosure Schedule), (c) operating leases, (d) deferred tax liabilities or (e) retirement benefit liabilities.
 
Indemnified Party” has the meaning set forth in Section 8(d).
 
Indemnifying Party” has the meaning set forth in Section 8(d).
 
Independent Accounting Firm” has the meaning set forth in Section 2(c)(iii)(E).
 
Intellectual Property” means all intellectual property and industrial property rights of any kind or nature of SM&P, including all U.S. and foreign (a) inventions, whether or not
 

 
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patentable, reduced to practice or made the subject matter of one or more pending patent applications, patents, patent applications, patent disclosures, and all related continuations, continuations-in-part, divisionals, reissues, re-examinations, substitutions, and extensions thereof  (b) trademarks, service marks, names, corporate names, trade names, domain names, logos, slogans, trade dress, and other similar designations of source or origin, together with the goodwill symbolized by any of the foregoing, (c) registered and unregistered copyrights and all applications to register the same and copyrightable subject matter, (d) computer programs (whether in source code, object code, or other form), algorithms, databases, compilations and data, technology supporting the foregoing, and all documentation, including user manuals and training materials, related to any of the foregoing that are solely owned by SM&P, (e) trade secrets and all other confidential information, business information (including pricing and cost information, business and marketing plans and customer and supplier lists), know-how (including techniques and research and development information), inventions, proprietary processes, formulae, models, and methodologies, (f) telephone numbers and Internet protocol addresses, and (g) all rights in the foregoing, (h) all applications and registrations for the foregoing, and (i) all rights and remedies against past, present, and future infringement, misappropriation, or other violation thereof.
 
Knowledge” means, with respect to the Seller, actual knowledge of the following representatives of the Seller and SM&P after reasonable inquiry or investigation:  Robert E. Shively, Kevin F. Beauchamp, Timothy M. Seelig, and Ryan Hyman.
 
Leased Real Property” has the meaning set forth in Section 4(p).
 
Material Adverse Effect” means a material adverse effect on the business, operations, properties, financial condition, assets or liabilities (including contingent liabilities) of SM&P, other than effects resulting from either (a) conditions generally affecting the industries in which SM&P operates, provided that SM&P is not adversely affected disproportionately in one or more material respects due to such conditions, (b) any change in law or GAAP or (c) the transactions contemplated by or otherwise permitted by this Agreement.
 
Material Agreement” has the meaning set forth in Section 4(g).
 
Multiemployer Plan” has the meaning set forth in ERISA Section 3(37).
 
New Laptop Expenditure” has the meaning set forth in Section 2(b).
 
Noncompete Period” has the meaning set forth in Section 6(e)(i).
 
Ordinary Course of Business” means the ordinary course of SM&P's business consistent with prior custom and practice (including with respect to quantity and frequency).
 
Owned Real Property” has the meaning set forth in Section 4(p).
 
Party” or “Parties” has the meaning set forth in the first paragraph of this Agreement.
 
PBGC” means the Pension Benefit Guaranty Corporation.
 

 
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“Permitted Encumbrances” means:
 

(i)     mechanic’s and materialmen’s liens and liens for ad valorem taxes and assessments that are not yet delinquent or, if delinquent, that are being contested in good faith and for which appropriate reserves have been established in accordance with GAAP;

(ii)     easements, rights-of-way, servitudes, permits, surface leases and other rights in respect of real property that do not materially interfere with the use of the property in the manner in which SM&P has historically used the property;

(iii)    rights reserved to or vested in any government, statutory, municipal or public authority to control or regulate the assets of SM&P, and all applicable laws, rules and orders of any governmental authorities;

(iv)     restrictions on transfer arising under applicable federal or state securities laws; and

(v)     all other liens, charges, encumbrances, defects or irregularities that individually or in the aggregate are not such as to materially interfere with the operation, value or use of the property or asset affected.
 
Person” means an individual, a partnership, a corporation, a limited liability company, an association, a joint stock company, a trust, a joint venture, an unincorporated organization or a governmental entity (or any department, agency or political subdivision thereof).
 
SM&P” has the meaning set forth in the first paragraph of this Agreement.
 
SM&P Benefit Plans” has the meaning set forth in Section 4(r).
 
SM&P Financial Statements” has the meaning set forth in Section 4(d).
 
SM&P Share” means any share of the common stock, $1.00 par value, of SM&P.
 
Post-Closing Period” means, with respect to SM&P, any Tax Period commencing after the Closing Date and the portion of any Straddle Period commencing after the Closing Date.
 
Pre-Closing Period” means, with respect to SM&P, any Tax Period ending on or before the Closing Date and the portion of any Straddle Period ending on the Closing Date.
 
Purchase Price” has the meaning set forth in Section 2(b).
 
Related Party Agreements has the meaning set forth in Section 4(q).
 
Securities Act” means the Securities Act of 1933, as amended.
 
Security Interest” means any mortgage, pledge, lien, encumbrance, charge or other security interest, other than Permitted Encumbrances.
 

 
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Seller” has the meaning set forth in the first paragraph of this Agreement.
 
Seller's Report” has the meaning set forth in Section 2(c)(iii)(B).
 
Straddle Period” means, with respect to SM&P, any Tax Period that begins before and ends after the Closing Date.
 
Tax” or “Taxes” means any net income, gross income, gross receipts, license, payroll, employment, excise, severance, stamp, occupation, windfall profits, environmental, ad valorem, customs duty, utility, production, capital stock, franchise, profits, withholding, social security (or similar), unemployment, disability, real property, personal property, sales, use, transfer, registration, value added, estimated or other tax of any kind whatsoever, including any interest, penalty or additions thereto, imposed by any taxing authority (domestic or foreign), whether disputed or not, including any liability for taxes pursuant to Treasury Regulation Section 1.1502-6 (or similar provision of state, local or foreign law).
 
Tax Allocation Agreement” has the meaning set forth in Section 9(g).
 
Tax Authority” means, with respect to any Tax, the governmental entity or political subdivision thereof that imposes such Tax, and the agency (if any) charged with the collection of such Taxes for such entity or subdivision, including any governmental or quasi-governmental entity or agency that imposes, or is charged with collecting, social security or similar charges or premiums.
 
Tax Benefit” means the present value of any refund, credit or reduction in otherwise required Tax payments including any interest payable thereon, which present value shall be computed as of the Closing Date or the first date on which the right to the refund, credit or other Tax reduction arises or otherwise becomes available to be utilized, whichever is later, (i) using the combined federal, state and local income Tax rate applicable to the highest level of income with respect to such Tax under the Applicable Tax Law on such date, and (ii) using the applicable rate on such date imposed on corporate deficiencies paid within 30 days of a notice of proposed deficiency under the Code or other Applicable Tax Law.  Any Tax Benefit shall be computed net of any related Tax cost (which shall be computed in the same manner in which Tax Benefits are otherwise computed pursuant to this definition).
 
Tax Period” means, with respect to any Tax, the period for which the Tax is reported as provided under Applicable Tax Law.
 
Tax Returns” means any return, including any information return, declaration, report, claim for refund, statement, schedule, notice, form or other document or information, filed, or required to be filed, in connection with the calculation, determination, assessment or collection or otherwise relating to any Tax.
 
Third Party Claim” has the meaning set forth in Section 8(d).
 
Title IV Plan” means any Employee Benefit Plan that is a defined benefit plan (as defined in ERISA 
Section 3(35)) and is subject to Title IV of ERISA.
 

 
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Treasury Regulation” means the U.S. federal income tax regulations, as amended.
 
Working Capital” means the difference between the value of current assets (excluding cash and cash equivalents) and current liabilities (excluding current portions of long-term debt and accrued interest thereon and deferred tax obligations) of SM&P.  Working Capital for the months of February 2007 through January 2008 are as shown on the attached Section 2(c) of the Disclosure Schedule.  Working Capital for any other months will be determined in accordance with the calculations set forth on the attached Section 2(c) of the Disclosure Schedule, applied on a basis consistent with the SM&P Financial Statements; provided, however, that in calculating the component line items of “Working Capital”, no effect shall be given to any assets, liabilities or obligations related to (i) any transactions between SM&P, on one hand, and the Seller or its Affiliates, on the other hand (excluding accounts receivable related to locating services provided by SM&P for Affiliates of Seller), other than those set forth on Section 2(c) of the Disclosure Schedule, (ii) any purchase accounting or other similar adjustments resulting from the consummation of the transactions between SM&P, on one hand, and the Seller or its Affiliates, on the other hand, (iii) any accrual with respect to any expenses related to the transactions between SM&P, on the one hand, and the Seller or its Affiliates, on the other hand, other than any amounts due as a result of any Tax Allocation Agreement, (iv) any Tax assets or Tax liabilities, arising outside of the Ordinary Course of Business, resulting from or in connection with the consummation of the transactions contemplated by this Agreement and (v) the New Laptops Expenditure.
 
Working Capital Closing Statement” has the meaning set forth in Section 2(c)(iii)(B).
 
Working Capital Increase” has the meaning set forth in Section 2(c)(iii)(H).
 
Working Capital Reduction” has the meaning set forth in Section 2(c)(iii)(H).
 
Working Capital Target” means as of the Closing Date, (i) the trailing twelve (12) month average of Working Capital as of the Closing Date (calculated in accordance with the procedures and methodology set forth in the definition of Working Capital), with the last month (i.e., the twelfth month) in such average determined as follows: (A) if the Closing occurs on the last business day of any month, the last month in such average shall be the month ended on the Closing Date (e.g., if the Closing occurs on March 31, the last month included in such average shall be March) and (B) if the Closing occurs on any day other than the last business day of the  month, the last month in such average shall be the preceding month end (e.g., if the Closing occurs on March 15, the last month included in such average shall be the month ended February); minus (ii) $3,400,000.
 
2.     PURCHASE AND SALE OF SM&P SHARES
 
(a)    Basic Transaction.  On and subject to the terms and conditions of this Agreement, the Buyer agrees to purchase from the Seller, and the Seller agrees to sell to the Buyer, all of the issued and outstanding SM&P Shares for the Final Adjusted Purchase Price.
 
(b)    Purchase Price.  The Buyer agrees to pay to the Seller at the Closing an amount equal to the sum of (i) $85,000,000 and (ii) the aggregate amount of capital expenditures made by SM&P on or after February 1, 2008 and prior to the Closing with respect to projects that the
 

 
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Buyer approves in writing, with such approval not to be unreasonably withheld; provided, that for the purpose of this clause (ii), the $517,000 purchase order for field laptops (the “New Laptops Expenditure”) and up to $500,000 of the other contemplated capital expenditures set forth on Schedule 2(b) of the Disclosure Schedules are deemed to be approved by the Buyer.  All of the foregoing shall be collectively referred to as the “Purchase Price,” which shall be subject to further adjustment pursuant to Section 2(c).
 
(c)    Purchase Price Adjustment.  The Purchase Price shall be adjusted as follows:
 
(i)     At Closing, the Purchase Price shall be increased or decreased (as adjusted, the “Estimated Adjusted Purchase Price”), as the case may be, on a dollar-for-dollar basis by the amount by which the Estimated Working Capital, is greater or less than the Estimated Working Capital Target.
 
(ii)     As soon as practicable (but in any event at least two business days prior to Closing), SM&P shall prepare and deliver to the Buyer an estimated calculation, as of the Closing, of the Working Capital (the “Estimated Working Capital”) and the Working Capital Target (the “Estimated Working Capital Target”).  Such calculation of the Estimated Working Capital is referred to herein as the “Estimated Working Capital Closing Statement”.  The Estimated Working Capital Closing Statement shall be prepared in conformity with the definition of Working Capital.  Such calculation of the Estimated Working Capital Target is referred to herein as the “Estimated Working Capital Target Closing Statement”.  The Estimated Working Capital Target Closing Statement shall be prepared in conformity with the definition of Working Capital Target.
 
(iii)    The Estimated Adjusted Purchase Price shall be subject to adjustment, if any, after the Closing Date as specified in this Section 2(c)(iii).
 
(A)    As soon as practicable following the Closing, the Buyer shall prepare a statement of (I) the Working Capital as of the Closing Date (the “Draft Working Capital Closing Statement”); and (II) the Working Capital Target as of the Closing Date (the “Draft Working Capital Target Closing Statement”).  The Draft Working Capital Closing Statement shall be prepared in conformity with the definition of Working Capital.  The Draft Working Capital Target Closing Statement shall be prepared in conformity with the definition of Working Capital Target.  The Buyer will deliver the Draft Working Capital Closing Statement and the Draft Working Capital Target Closing Statement to the Seller not later than 45 calendar days following the Closing Date.
 
(B)    The Draft Working Capital Closing Statement shall be final and binding upon the Parties, and shall be deemed to be the Working Capital Closing Statement, unless, within 30 calendar days after receipt of the Draft Working Capital Closing Statement and the Draft Working Capital Target Closing Statement from the Buyer, the Seller shall provide to the Buyer a report indicating its objections, if any, to the Draft Working Capital Closing Statement.  Any such objections shall be set forth in reasonable detail in a report (the “Seller's Report on Working Capital”) that shall indicate the grounds upon which the Seller
 

 
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disputes the Buyer's calculation of the Draft Working Capital Closing Statement.  The Buyer shall provide to the Seller full access, during normal business hours, to the books and records of SM&P and to SM&P's personnel and accountants in connection with the Seller's review of the Draft Working Capital Closing Statement and with the Seller's preparation of the Seller's Report on Working Capital.
 
(C)    The Draft Working Capital Target Closing Statement shall be final and binding upon the Parties, and shall be deemed to be the Working Capital Target Closing Statement, unless, within 30 calendar days after receipt of the Draft Working Capital Target Closing Statement and the Draft Working Capital Closing Statement from the Buyer, the Seller shall provide to the Buyer a report indicating its objections, if any, to the Draft Working Capital Target Closing Statement.  Any such objections shall be set forth in reasonable detail in a report (the “Seller's Report on Working Capital Target”) that shall indicate the grounds upon which the Seller disputes the Buyer's calculation of the Draft Working Capital Target Closing Statement.  The Buyer shall provide to the Seller full access, during normal business hours, to the books and records of SM&P and to SM&P's personnel and accountants in connection with the Seller's review of the Draft Working Capital Target Closing Statement and with the Seller's preparation of the Seller's Report on Working Capital Target.
 
(D)    Within 30 calendar days after the receipt by the Buyer of the Seller's Report on Working Capital and the Seller’s Report on Working Capital Target, the Seller and the Buyer shall endeavor in good faith to agree on any matters in dispute.
 
(E)    If the Buyer and the Seller are unable to agree on any matters in dispute within 30 calendar days after receipt by the Buyer of the Seller's Report on Working Capital and the Seller’s Report on Working Capital Target, the matters in dispute will be submitted for resolution to an independent accounting firm of national reputation as may be mutually acceptable to the Buyer and the Seller, provided, however, if the Parties are unable to agree on a mutually acceptable accounting firm within such 30-day period, such firm shall be appointed in accordance with the arbitrator selection process of the American Arbitration Association (the “Independent Accounting Firm”). The Independent Accounting Firm shall agree to determine and issue a written report to the Seller and the Buyer regarding such disputed items, within 30 calendar days after such submission.  Such written decision shall be final and binding upon the Parties. The Independent Accounting Firm shall be instructed to resolve only those items in dispute and the Independent Accounting Firm's decision shall be based solely on written submissions by the Seller and the Buyer.  The Independent Accounting Firm may not assign a value greater than the greatest value for such item claimed by either Party or smaller than the smallest value for such item claimed by either Party.  The working capital statement incorporating the resolution of matters in dispute with respect to Working Capital (or, if the Seller's Report on Working Capital is not provided within the time prescribed in Section 2(c)(iii), the Draft
 

 
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Working Capital Closing Statement) is referred to as the “Working Capital Closing Statement.”  The Working Capital Closing Statement shall have the legal effect of an arbitral award and shall be final, binding and conclusive on the Parties.   The Working Capital Target Statement incorporating the resolution of matters in dispute with respect to Working Capital Target (or, if the Seller's Report on Working Capital Target is not provided within the time prescribed in Section 2(c)(iii), the Draft Working Capital Target Closing Statement) is referred to as the “Working Capital Target Closing Statement.”  The Working Capital Target Closing Statement shall have the legal effect of an arbitral award and shall be final, binding and conclusive on the Parties.  Judgment may be entered upon the amount payable hereunder in accordance with the determination of the Independent Accounting Firm in any court having jurisdiction over the Party against which such determination is to be enforced.  The fees and expenses of the Independent Accounting Firm incurred pursuant to this Section 2(c)(iii) shall be borne by the party whose aggregate disputed amount is farthest away from the aggregate determination of the Independent Accounting Firm.  The Seller and the Buyer shall cooperate with each other and each other's representatives to enable the Independent Accounting Firm to render a written decision as promptly as possible.
 
(F)    The parties agree to execute customary engagement letters with the Independent Accounting Firm in connection with its engagement hereunder.
 
(G)    Upon the completion of the Working Capital Closing Statement and the Working Capital Target Closing Statement the following calculation shall be made (with the result being the “Final Adjusted Purchase Price”): the amount equal to the Purchase Price, plus or minus, as the case may be, the amount by which final Working Capital (calculated by reference to the Working Capital Closing Statement) is greater or less than the final Working Capital Target (calculated by reference to the Working Capital Target Closing Statement).
 
(H)    If the Final Adjusted Purchase Price is less than the Estimated Adjusted Purchase Price, the Estimated Adjusted Purchase Price shall be reduced by an amount equal to such shortfall (the “Working Capital Reduction”).  The Seller shall pay to the Buyer the amount of the Working Capital Reduction.  If the Final Adjusted Purchase Price is greater than the Estimated Adjusted Purchase Price, the Estimated Adjusted Purchase Price shall be increased by an amount equal to such excess (the “Working Capital Increase”).  The Buyer shall pay to the Seller the amount of the Working Capital Increase.
 
(I)    Any payments to be made pursuant to Section 2(c)(iii)(H) shall be made in cash within ten calendar days after the date of receipt by the Buyer and the Seller of the Working Capital Closing Statement and Working Capital Target Closing Statement as finally established pursuant to this Section 2(c)(iii).
 
(d)    The Closing.  The closing of the transactions contemplated by this Agreement (the “Closing”) shall take place at 720 Olive Street, 15th Floor, St. Louis, Missouri 63101,
 

 
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commencing at 9:00 a.m. local time on the second business day after all conditions to the obligations of the Parties to consummate the transactions contemplated hereby (other than the conditions with respect to actions the Parties will take at the Closing itself) are satisfied or waived or such other date as the Buyer and the Seller may mutually determine (the “Closing Date”).
 
(e)    Deliveries at the Closing.  At the Closing, (i) the Seller will deliver to the Buyer the various certificates, instruments and documents referred to in Section 7(a), (ii) the Buyer will deliver to the Seller the various certificates, instruments and documents referred to in Section 7(b), (iii) the Seller will deliver to the Buyer stock certificates representing all of the SM&P Shares endorsed in blank or accompanied by duly executed assignment documents, and (iv) the Buyer will deliver to the Seller the Estimated Adjusted Purchase Price by wire transfer of immediately available funds to an account designated by the Seller at least two business days prior to the Closing.
 
3.     REPRESENTATIONS AND WARRANTIES CONCERNING THE TRANSACTION
 
(a)    Representations and Warranties of the Seller.  The Seller represents and warrants to the Buyer that the statements contained in this Section 3(a) are true and correct as of the date of this Agreement:
 
(i)      Organization of the Seller.  The Seller is a corporation duly organized, validly existing, and in good standing under the laws of the State of Missouri.
 
(ii)     Authorization of Transaction.  The Seller has full power and authority (including full corporate power and authority) to execute and deliver this Agreement and has all requisite power and authority to perform its obligations hereunder.  This Agreement constitutes the valid and legally binding obligation of the Seller, enforceable in accordance with its terms and conditions, subject to the effects of bankruptcy, insolvency, reorganization, moratorium or similar laws affecting creditor's rights generally and to general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law).  Except for any filing required under the HSR Act, to the extent applicable, and subject to the expiration or termination of the waiting period arising thereunder, the Seller is not required to give any notice to, make any filing with or obtain any authorization, consent or approval from any government or governmental agency to consummate the transactions contemplated by this Agreement, except for notices, filings, authorizations, consents or approvals that, if not made or obtained, would not adversely affect the Seller's ability to consummate the transactions contemplated by this Agreement.
 
(iii)    Noncontravention.  Neither the execution and the delivery of this Agreement nor the consummation of the transactions contemplated hereby will (A) violate any constitution, statute, regulation, rule, injunction, judgment, order, decree, ruling, charge or other restriction of any government, governmental agency or court to which the Seller is subject or any provision of its charter or bylaws or (B) conflict with, result in a breach of, constitute a default under, result in the acceleration of, create in any
 

 
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party the right to accelerate, terminate, modify or cancel, or require any notice under, any agreement, contract, lease, license, instrument or other arrangement to which the Seller is a party or by which it is bound or to which any of its assets is subject, except for such violations, defaults, breaches or other occurrences that, individually or in the aggregate, would not have, or be reasonably likely to have, a material adverse effect on the Seller and will not adversely affect the Seller's ability to consummate the transactions contemplated by this Agreement.
 
(iv)    Brokers' Fees.  The Seller has no liability or obligation to pay any fees or commissions to any broker, finder or agent with respect to the transactions contemplated by this Agreement for which the Buyer or SM&P is or could become liable or obligated.
 
(v)     SM&P Shares.  The Seller holds of record and owns beneficially 100 SM&P Shares, which represent all of the issued and outstanding capital stock of SM&P, free and clear of any restrictions on transfer (other than restrictions under federal and state securities laws), taxes, Security Interests, options, warrants, purchase rights, contracts, commitments, equities, claims and demands.  The Seller is not a party to any option, warrant, purchase right or other contract or commitment that could require the Seller to sell, transfer or otherwise dispose of any capital stock of SM&P (other than this Agreement).  The Seller is not a party to any voting trust, proxy or other agreement or understanding with respect to the voting of any capital stock of SM&P.  Upon consummation of the Closing, the Buyer will receive good and marketable title to the SM&P Shares, which SM&P Shares will represent all of the issued and outstanding securities of SM&P and which will be free and clear of all liens, encumbrances and other third-party claims arising due to actions by the Seller.
 
(b)    Representations and Warranties of the Buyer.  The Buyer represents and warrants to the Seller that the statements contained in this Section 3(b) are true and correct as of the date of this Agreement:
 
(i)     Organization of the Buyer.  The Buyer is a corporation duly organized, validly existing, and in good standing under the laws of the State of Delaware.
 
(ii)    Authorization of Transaction.  The Buyer has full power and authority (including full corporate power and authority) to execute and deliver this Agreement and has all requisite power and authority to perform its obligations hereunder.  This Agreement constitutes the valid and legally binding obligation of the Buyer, enforceable in accordance with its terms and conditions, subject to the effects of bankruptcy, insolvency, reorganization, moratorium or similar laws affecting creditor's rights generally and to general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law).  Except for any filing required under the HSR Act, to the extent applicable, and subject to the expiration or termination of the waiting period arising thereunder, the Buyer is not required to give any notice to, make any filing with or obtain any authorization, consent or approval from any government or governmental agency to consummate the transactions contemplated by this Agreement, except for notices, filings, authorizations, consents or approvals that, if not made or
 

 
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obtained, would not adversely affect the Buyer's ability to consummate the transactions contemplated by this Agreement.
 
(iii)    Noncontravention.  Neither the execution and the delivery of this Agreement nor the consummation of the transactions contemplated hereby will (A) violate any constitution, statute, regulation, rule, injunction, judgment, order, decree, ruling, charge or other restriction of any government, governmental agency or court to which the Buyer is subject or any provision of its charter or bylaws or (B) conflict with, result in a breach of, constitute a default under, result in the acceleration of, create in any party the right to accelerate, terminate, modify or cancel, or require any notice under, any agreement, contract, lease, license, instrument or other arrangement to which the Buyer is a party or by which it is bound or to which any of its assets is subject, except for such violations, defaults, breaches or other occurrences that, individually or in the aggregate, would not have, or be reasonably likely to have, a material adverse effect on the Buyer and will not materially adversely affect the Buyer's ability to consummate the transactions contemplated by this Agreement.
 
(iv)    Brokers' Fees.  The Buyer has no liability or obligation to pay any fees or commissions to any broker, finder or agent with respect to the transactions contemplated by this Agreement for which the Seller could become liable or obligated.
 
(v)      Investment.  The Buyer is acquiring the SM&P Shares solely for its own account for investment purposes and not with a view to any distribution thereof within the meaning of the Securities Act.  The Buyer understands that the SM&P Shares are “restricted securities” under applicable federal and state securities laws and that, pursuant to these laws, the SM&P Shares may not be sold, transferred or otherwise disposed of without registration under the Securities Act and under any applicable state securities law or an exemption therefrom, and that in the absence of an effective registration statement covering the SM&P Shares or an available exemption from registration under the Securities Act and any applicable state securities laws, the SM&P Shares must be held indefinitely.
 
(vi)    Financing.  The Buyer has received (i) the commitment letter, dated February 4, 2008, among the Buyer and General Electric Capital Corporation, an affiliate of GE Antares Capital Corp. (the “Debt Financing Commitment”) and (ii) the equity commitment letter, dated February 4, 2008, between Kohlberg Management VI, LLC and the Buyer (the “Equity Financing Commitment” and together with the Debt Financing Commitment, the “Financing Commitments”).  A true, correct and complete copy of the Debt Financing Commitment and a true, correct and complete copy of the Equity Financing Commitment are attached hereto as Section 3(b)(vi)-1 and Schedule 3(b)(vi)-2 of the Disclosure Schedule, respectively.  The Financing Commitments provide the Buyer with aggregate financing sufficient to consummate the transactions contemplated by this Agreement and to pay all related fees and expenses associated therewith.  The obligations to fund the commitments under the Financing Commitments are not subject to any condition, other than the conditions expressly set forth in the Financing Commitments. As of the date hereof, no amendment or modification of any of the Financing Commitments is contemplated by any party thereto, and the respective
 

 
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commitments contained in the Financing Commitments have not been withdrawn or rescinded in any respect.  There are no fees, expense reimbursement obligations or other amounts that are required to be paid by Buyer prior to Closing under or in respect of the Financing Commitments.
 
(vii)    No Implied Warranties.  The Buyer is experienced and knowledgeable with respect to the industries in which SM&P operates and is aware of the risks in those industries.  The Buyer acknowledges and agrees that neither the Seller nor any of its Affiliates nor any Person acting on behalf of any of them is making any representation or warranty with respect to SM&P or the transactions contemplated by this Agreement except as expressly set forth in Section 3(a), Section 4 or the certificates delivered pursuant to Sections 7(a)(v) and (vi).  In particular, neither the Seller nor any of its Affiliates nor any Person acting on behalf of any of them makes any representation or warranty with respect to (i) the confidential Briefing Memorandum or the Supplemental Offering Memorandum furnished by the Seller, (ii) any financial projection or forecast relating to SM&P or its business, or (iii) except as expressly set forth in Section 3(a), Section 4 or the certificates delivered pursuant to Sections 7(a)(v) and (vi), any other information provided by or on behalf of the Seller with respect to SM&P and its business.  In entering into this Agreement, the Buyer acknowledges and affirms that it has relied and will rely solely on the terms of this Agreement and upon its independent analysis, evaluation and investigation of, and judgment with respect to, the business, economic, legal, tax or other consequences of the transactions contemplated by this Agreement, including its own estimate and appraisal of the extent and value of, and the risks associated with, the industries in which SM&P operates.
 
4.     REPRESENTATIONS AND WARRANTIES OF THE SELLER CONCERNING SM&P.  The Seller represents and warrants to the Buyer that the statements contained in this Section 4 are true and correct as of the date of this Agreement:
 
(a)    Organization, Qualification and Corporate Power.  SM&P (i) is a corporation duly organized and validly existing under the laws of the State of Indiana, (ii) is duly authorized to conduct business and is in good standing under the laws of each jurisdiction where such qualification is required, except where the lack of such qualification would not have, or be reasonably likely to have, a Material Adverse Effect and (iii) has full power and authority to carry on the businesses in which it is engaged and to own and use the properties owned and used by it.
 
(b)    Capitalization.  The entire authorized capital stock of SM&P consists of 1,000 SM&P Shares, of which 100 SM&P Shares are issued and outstanding.  All of the issued and outstanding SM&P Shares have been duly authorized, are validly issued, fully paid and nonassessable and are held beneficially and of record by the Seller.  There are no outstanding or authorized options, warrants, purchase rights, subscription rights, conversion rights, exchange rights or other contracts or commitments that could require SM&P to issue, sell or otherwise cause to become outstanding any of its capital stock.  There are no outstanding or authorized stock appreciation, phantom stock, profit participation or similar rights with respect to SM&P.  SM&P owns 100% of the issued and outstanding shares of capital stock of Colcom, Inc., a Texas corporation which currently has no active business operations.  Except with respect to Colcom,
 

 
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Inc., SM&P does not own or hold any shares of stock or any other security or interest in any other Person or any rights to acquire any such stock or any other interest.  
 
(c)    Noncontravention.  Assuming the accuracy of the Buyer’s representations and warranties set forth in Section 3 of this Agreement, neither the execution and the delivery of this Agreement nor the consummation of the transactions contemplated hereby will (i) violate any material constitution, statute, regulation, rule, injunction, judgment, order, decree, ruling, charge or other restriction of any government, governmental agency or court to which SM&P is subject or any provision of the charter or bylaws of SM&P or (ii) except as set forth in Section 4(c) of the Disclosure Schedule, conflict with, result in a breach of, constitute a default under, result in the acceleration of, create in any party the right to accelerate, terminate, modify or cancel, or require any notice under, any agreement, contract, lease, license, instrument or other arrangement to which SM&P is a party or by which it is bound or to which any of its assets is subject (or result in the imposition of any Security Interest upon any of its assets), except, in the case of clause (ii) hereof, where the violation, conflict, breach, default, acceleration, termination, modification, cancellation, failure to give notice or Security Interest would not have, or be reasonably likely to have, a Material Adverse Effect.  Except for any filing required under the HSR Act, to the extent applicable, and for the consents set forth on Section 4(c) of the Disclosure Schedule and subject to the expiration or termination of the waiting period arising thereunder, SM&P is not required to give any notice to, make any filing with or obtain any authorization, consent or approval from any government or governmental agency or other third party in order for the Parties to consummate the transactions contemplated by this Agreement, except where the failure to give notice, to file or to obtain any authorization, consent or approval would not have, or be reasonably likely to have, a Material Adverse Effect or materially adversely affect the ability of the Parties to consummate the transactions contemplated by this Agreement.
 
(d)    Financial Statements.  Attached hereto as Exhibit A are unaudited income statements and balance sheets of SM&P as of and for the fiscal years ended September 30, 2006 and September 30, 2007 and as of November 30, 2007 and for the two-month period then ended (collectively, the “SM&P Financial Statements”).  The SM&P Financial Statements fairly present in all material respects the financial condition and results of operations of SM&P in accordance with GAAP consistently applied, except as otherwise expressly set forth in the SM&P Financial Statements or on Section 4(d) of the Disclosure Schedule, and except that such financial statements do not include footnotes required by GAAP.
 
(e)    Title to Personal Property.  Except as set forth on Section 4(e) of the Disclosure Schedule, SM&P has good, valid and marketable title to the personal property that it purports to own, including all personal property reflected on the unaudited balance sheet as of November 30, 2007 included in the SM&P Financial Statements, to conduct its business as currently conducted and holds such personal property free and clear of all Security Interests, except Permitted Encumbrances.
 
(f)    Legal Compliance.  SM&P is in compliance with all applicable laws (including rules, regulations, codes, plans, injunctions, judgments, orders, decrees, rulings and charges thereunder) of federal, state, local and foreign governments (and all agencies thereof) except for such failures to comply that, individually or in the aggregate, would not have, or be reasonably likely to have, a Material Adverse Effect.  SM&P has all permits, licenses, certificates of
 

 
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authority, orders and approvals of, and has made all filings, applications and regulations with, federal, state, local or foreign government or regulatory bodies that are currently required to permit it to carry on its business as presently conducted, the absence of which, individually or in the aggregate, would have, or be reasonably likely to have, a Material Adverse Effect. There is no default on the part of SM&P or any other party under, nor does there exist any grounds for revocation, suspension or limitation of, any of such permits, licenses, certificates of authority, orders and approvals Licenses or Permits, which, individually or in the aggregate, would not have, or be reasonably likely to have, a Material Adverse Effect.  
 
(g)    Contracts.  Section 4(g) of the Disclosure Schedule lists each written contract and other written agreement to which SM&P is a party, (i) the performance of which will involve consideration in excess of $500,000 per year or $2.5 million in the aggregate, (ii) that contains a covenant not to compete, or other material covenant restricting the development, manufacture, marketing or distribution of products and services of SM&P, in each case that materially limits the conduct of the business of SM&P as presently conducted; (iii) that relates to the acquisition or disposition of any material business by SM&P (whether by merger, sale of stock, sale of assets or otherwise); (iv) that imposes any confidentiality, standstill or similar obligation on SM&P, except for those entered into in the ordinary course of business or in connection with the sale process of SM&P; (v) that contains a right of first refusal, first offer or first negotiation; (vi) in respect of any joint venture, partnership or strategic alliance; and (vii) pursuant to which SM&P has granted any exclusive marketing, sales representative relationship, franchising, consignment or distribution right to any third party (collectively, the “Material Agreements”).  The Seller has made available to the Buyer a correct and complete copy of each contract or agreement listed in Section 4(g) of the Disclosure Schedule.  Except as set forth in Section 4(g) of the Disclosure Schedule:  (i) each Material Agreement is in full force and effect and is valid and enforceable against SM&P in accordance with its terms, except as such enforceability may be limited by laws affecting creditors’ rights generally and to the availability of equitable remedies; (ii) SM&P is, and at all times since January 1, 2006 has been, in full compliance in all material respects with all applicable terms and requirements of each Material Agreement under which SM&P has or had any obligation or liability or by which SM&P or any of the assets owned or used by SM&P is or was bound; (iii) to the Seller's Knowledge, each other Person that has or had any obligation or liability under any Material Agreement under which SM&P has or had any rights is, and at all times since January 1, 2006 has been, in material compliance with all applicable terms and requirements of such Material Agreement; (iv) no event has occurred or circumstance exists that (with or without notice or lapse of time) may reasonably be expected to contravene, conflict with, or result in a violation nor breach of, or give SM&P or other Person the right to declare a default or exercise any remedy under, or to accelerate the maturity or performance of, or to cancel, terminate, or modify, any Material Agreement; (v) to the Seller's Knowledge, SM&P has not given to or received from any other Person, at any time since January 1, 2006, any notice or other communication (whether oral or written) regarding any violation or breach of, or default under, any Material Agreement; and (vi) to the Seller's Knowledge, there are no renegotiations of, attempts to renegotiate, or outstanding rights to renegotiate any material amounts paid or payable to SM&P under current or completed Material Agreements with any Person, and no such Person has made written demand to SM&P for such renegotiation.
 
(h)    Litigation.  Section 4(h) of the Disclosure Schedule sets forth each instance in which SM&P (i) is subject to any outstanding injunction, judgment, order, decree, ruling or
 

 
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charge, (ii) is a party to any action, suit, proceeding, hearing or investigation of, in or before any court or quasi-judicial or administrative agency of any federal, state, local or foreign jurisdiction, or (iii) to the Seller’s Knowledge, is threatened to be made a party to any such proceeding, except in each case where the injunction, judgment, order, decree, ruling, action, suit, proceeding, hearing or investigation involves aggregate claims less than $500,000.  
 
(i)    Environmental Matters.  
 
(i)    To the Seller's Knowledge, SM&P is in substantial compliance with all applicable federal, state, and local laws, ordinances, rules and regulations relating to protection of public health or the environment, including the Comprehensive Environmental Response, Compensation, and Liability Act of 1980, as amended, 42 U.S.C. Section 9601, et seq., the Resource Conservation and Recovery Act of 1976, as amended, 42 U.S.C. Section 6901, et seq., the Clean Air Act, 42 U.S.C. Section 7401, et seq., as amended; the Federal Water Pollution Control Act, 33 U.S.C. Section 1251, et seq., as amended; the Oil Pollution Act of 1990, 33 U.S.C. Section 2701, and the Occupational Health and Safety Act, 29 USC Section 651, et seq. (collectively, “Environmental Laws”), and SM&P has not used or disposed of Hazardous Substances on the real property owned or operated by SM&P except in material compliance with Environmental Laws and except for such matters that individually or in the aggregate do not have, or be reasonably likely to have, a Material Adverse Effect.
 
(ii)    To the Seller's Knowledge, SM&P has obtained and is in substantial compliance with all permits, licenses, franchises, authorities, consents and approvals as are necessary under applicable Environmental Laws for operating its assets and business as presently conducted, and all such permits, licenses, franchises, authorities, consents and approvals remain in full force and effect, except for such matters that, individually or in the aggregate, would not reasonably be expected to have a Material Adverse Effect.
 
(iii)    There are no pending or, to the Seller's Knowledge, threatened claims, demands, actions, administrative proceedings, lawsuits or investigations (a) against SM&P under any Environmental Laws or (b) arising from any activities of SM&P not in compliance with any Environmental Laws except for claims, demands, actions, administrative proceedings, lawsuits or investigations that, individually or in the aggregate, would not reasonably be expected to have a Material Adverse Effect.
 
(iv)    None of the real property currently owned or operated or, to the Seller's Knowledge, previously owned or operated by SM&P is (a) listed on the National Priorities List or any similar list of sites requiring remedial action or (b) the subject of any regulatory action that is reasonably anticipated by the Seller to lead to claims against SM&P under any Environmental Law.
 
Notwithstanding any other provision of this Agreement, the Seller makes no representation in this Agreement regarding any compliance or failure to comply with, or any actual or contingent liability under, any Environmental Law, except as set forth in this Section 4(i).
 

 
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(j)    Insurance.  SM&P maintains insurance coverages, in such amounts and covering such risks and with such limitations, deductibles and retentions, as are customary for similarly situated businesses.  Section 4(j) of the Disclosure Schedule lists and briefly describes each insurance policy maintained by SM&P with respect to its properties, assets and business, together with a claims history for the past three years and an indication of whether such policy provides coverage on an “occurrence” or “claims made” basis.  Except as set forth on Section 4(j) of the Disclosure Schedule, all of such insurance policies are in full force and effect, SM&P is not in default with respect to its obligations under any such insurance policy, and since January 1, 2006, SM&P has not been denied insurance coverage.  Except as set forth in Section 4(j) of the Disclosure Schedule, SM&P has no self-insurance or co-insurance programs.
 
(k)    Employee Relations.  SM&P is in substantial compliance with all federal, state, local or foreign laws, ordinances, rules and  regulations respecting employment and employment practices, terms and conditions of employment and wages and hours, and has not and is not engaged in any unfair labor practice, except for such matters that, individually or in the aggregate, would not reasonably be expected to have a Material Adverse Effect.  No unfair labor practice complaint against SM&P is pending before the National Labor Relations Board.  There is no labor strike, jurisdictional dispute, material slowdown or stoppage pending or, to the Seller’s Knowledge, threatened against or involving SM&P, nor has there been any such strike, jurisdictional dispute, slowdown or stoppage during the past two years.  There are no representation proceedings involving SM&P pending or, to the Seller’s Knowledge, threatened with the National Labor Relations Board, and no labor union or group of SM&P employees has made a demand for recognition which is currently pending.
 
(l)    Taxes.
 
(i)    Tax Returns Filed and Taxes Paid.  Except as set forth in Section 4(1) of the Disclosure Schedule, (A) SM&P has duly filed or caused to be filed, on or before the due date thereof (taking into account timely extensions), with the appropriate taxing authorities, all Tax Returns that it is required to file; (B) each such Tax Return (including any amendment thereto) is true, correct, and complete in all material respects; (C) all Taxes of SM&P due with respect to, or shown or required to be shown to be due on, each such Tax Return (or amendment) or subsequent assessment with regard thereto, have been timely paid, or, an adequate reserve has been established therefore on the books and records of SM&P; and (D) there are no extensions of time to file any Tax Returns that are pending.
 
(ii)    Tax Reserves and Tax Liabilities.  Except as set forth in Section 4(1) of the Disclosure Schedule, (A) the amount of SM&P's liability for unpaid Taxes for all periods ending on or before the Closing Date shall not, in the aggregate, exceed the amount of the current liability reserve for Taxes (excluding accruals for deferred Taxes) as reflected on the books and records of SM&P on the Closing Date;  (B) SM&P has collected or withheld all Taxes that it is required to collect or withhold; and (C) there are no liens on any of SM&P's assets that have arisen in connection with any failure (or alleged failure) to pay any Taxes except any lien for Taxes that are being contested in good faith or is for property Taxes that are not yet delinquent.
 

 
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(iii)    Audit History and Other Proceedings.  Except as set forth in Section 4(1) of the Disclosure Schedule, (A) there are no pending audits, investigations, claims, suits or other proceedings for or relating to any material liability of SM&P in respect of Taxes; (B) SM&P is not delinquent in the payment of any Taxes; (C) no material deficiencies for Taxes of SM&P have been claimed, proposed or assessed by any taxing or other governmental authority; (D) there are no matters under discussion between SM&P and any governmental authority which could result in any additional amount of Taxes; (E) no extension of a statute of limitations (whether arising by reason of a waiver, claim for refund, or otherwise) relating to Taxes or Tax Returns of SM&P is in effect; and (F) there are no pending requests for rulings or determinations in respect of Taxes of SM&P pending with any governmental authority.  Seller shall prepare any consolidated or combined Tax Return for which SM&P or the Buyer shall be liable to make payments to Seller pursuant to Section 9(e) on a basis consistent with prior practice and Applicable Tax Law.
 
(iv)    Miscellaneous.  Except as set forth in Section 4(1) of the Disclosure Schedule, (A) SM&P does not own any real property in the State of New York or any other jurisdiction in which a Tax is imposed upon the transfer of securities of an issuer having an interest in real property; (B) SM&P has not made any payments, is not obligated to make any payments, nor is a party to any agreement that could obligate it to make any payments that will not be deductible under Section 280G of the Code; (C) SM&P has not been a United States real property holding corporation within the meaning of Section 897(c)(2) of the Code during the applicable periods specified in Section 897(c)(1)(A)(ii) of the Code; (D) SM&P has not violated any of the COBRA continuation coverage requirements set forth in Section 4980B of the Code; (E) SM&P has disclosed on its federal income Tax Return all positions taken therein that could give rise to substantial understatement of federal income Taxes within the meaning of Section 6662 of the Code; (F) SM&P has not agreed to and is not required to make any adjustment under Section 481(a) of the Code by reason of a change in accounting method which affects any taxable year beginning after December 31, 2004; (G) SM&P has no application pending with any taxing authority requesting permission for any changes in accounting methods that affects any taxable year beginning after December 31, 2004; (H) no property owned by SM&P (1) is property required to be treated as being owned by another person pursuant to the provisions of Section 168(f)(8) of the Internal Revenue Code of 1954, as amended, and in effect immediately prior to the enactment of the Tax Reform Act in 1986, (2) constitutes “tax-exempt use property” within the meaning of Section 168(h)(1) of the Code; and (3) is tax-exempt bond financed property within the meaning of Section 168(f) of the Code; and (I) SM&P is not a foreign person within the meaning of Section 1445 of the Code.  Section 4(1) of the Disclosure Schedule contains an accurate list of all states, counties, cities and other taxing jurisdictions (whether foreign or domestic) to which any Tax is properly payable by SM&P.
 
(m)    Events After September 30, 2007.  Since September 30, 2007, there have not been any changes in the assets, conditions or affairs, financial or otherwise, of SM&P that, individually or in the aggregate, would reasonably be expected to have a Material Adverse Effect.
 

 
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(n)    Customers.  Section 4(n) of the Disclosure Schedule sets forth the names of SM&P's 22 largest customers based on revenues for the 12 months ended September 30, 2007.  Except as set forth on Section 4(n) of the Disclosure Schedule, as of the date hereof, SM&P has not received notice that any of such customers intends to cease or materially reduce its business with SM&P or to terminate any Material Agreement with SM&P.
 
(o)    Condition of Personal Property.  Except as expressly set forth in this Agreement, SM&P makes no and disclaims any representation or warranty, whether express or implied and whether by common law, statute or otherwise, as to (i) the quality, condition or operability of any personal property or equipment, (ii) its merchantability, (iii) its fitness for any particular purpose or (iv) its conformity to models or samples of materials, and all personal property and equipment is delivered “AS IS, WHERE IS” in the condition in which the same exists.
 
(p)    Real Property.
 
(i)    Section 4(p) of the Disclosure Schedule accurately lists all real property that SM&P owns (the “Owned Real Property”) and every lease or similar agreement under which SM&P is lessee of, or holds or operates, any real property owned by any third Person with an annual cost to SM&P in excess of $50,000 per year (the “Leased Real Property”).  The Seller will make available to the Buyer after execution of this Agreement and prior to Closing true and complete copies of all deeds, leases and other instruments by which SM&P acquired or leases any real property and any title policies in SM&P's possession with respect to such Owned Real Property.
 
(ii)    SM&P has good and marketable title to the Owned Real Property, free and clear of any Security Interest, except for Permitted Encumbrances.  Except as set forth in Section 4(p) of the Disclosure Schedule, there are no leases, subleases, licenses, concessions or other agreements granting to any party or parties the right of use or occupancy of any portion of the Owned Real Property.  There are no outstanding options or rights of first refusal to purchase any of the Owned Real Property or any portion thereof or interest therein.  All of the Owned Real Property and Leased Real Property are currently zoned in the zoning category which permits operation of such properties as now used, operated and maintained for the operation of the Business, except for such non-compliance was would not have, or be reasonably likely to have, a Material Adverse Effect. None of the Owned Real Property or the Leased Real Property nor its respective use is in violation of any local governmental rule, ordinance, regulation or building code, except for such violation as would not have, or be reasonably likely to have, a Material Adverse Effect.
 
(iii)    SM&P has a valid leasehold interest in, and the right to quiet enjoyment of, all Leased Real Property for the full term of each applicable lease or similar agreement (and any renewal option related thereto), and the leasehold or other interest of SM&P in such Leased Real Property is not subject or subordinate to any Security Interest granted by SM&P.
 

 
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(q)    Transactions with Affiliates.  Section 4(q) of the Disclosure Schedule lists all (i) oral or written contracts and agreements between SM&P and the Seller and Affiliates of the Seller and (ii) all services provided by the Seller and Affiliates of the Seller to SM&P not otherwise covered by such oral or written contracts and agreements (collectively, the “Related Party Agreements”).
 
(r)    Employee Benefits.  
 
(i)    Section 4(r) of the Disclosure Schedule sets forth a true and complete list of all Employee Benefit Plans maintained or contributed to by SM&P or the Seller during the past three years for the benefit or of with respect to any current or former employees of SM&P (the “SM&P Benefit Plans”).
 
(ii)    Each of the SM&P Benefit Plans has been administered in substantial compliance with its terms and, where applicable, with ERISA, the Code and all other applicable statutes and regulations.  SM&P has performed and complied in all material respects with all of its obligations under or with respect to each of the SM&P Benefit Plans.
 
(iii)    SM&P does not currently maintain or contribute to, and at no time in the past has it maintained or contributed to, a Multiemployer Plan, a Title IV Plan or a plan subject to Section 302 of ERISA or Section 412 of the Code.
 
(iv)    Each SM&P Benefit Plan that is an Employee Pension Benefit Plan, and that is intended to be qualified under Section 401(a) of the Code is the subject of a favorable Internal Revenue Service determination letter.  There is no pending or, to the Seller's Knowledge, threatened litigation relating to any SM&P Benefit Plan (other than routine claims for benefits), and there is no proceeding that is pending or, to the Seller's Knowledge, threatened by any governmental agency with respect to any SM&P Benefit Plan.
 
(v)    Neither SM&P nor any of its respective employees nor, to the Seller's Knowledge, any fiduciary of any SM&P Benefit Plan or any other person has engaged in any transaction, including the execution and delivery of this Agreement, and other agreements, instruments and documents for which execution and delivery by SM&P is contemplated herein, in violation of Section 406(a) or (b) of ERISA, or which is a prohibited transaction (as defined in Section 4975(c)(1) of the Code), or which could subject SM&P to any tax or penalty imposed by Chapter 43 of subtitle D of the Code or Sections 502(c), (i) or (1) of ERISA in an amount that would be material.
 
(vi)    With respect to any employee benefit plan, within the meaning of Section 3(3) of ERISA, which is not listed in Section 4(r) of the Disclosure Schedule but which is sponsored, maintained or contributed to, or has been sponsored, maintained or contributed to within six years prior to the Closing Date, by SM&P, (A) no withdrawal liability, within the meaning of Section 4201 of ERISA, has been incurred, which withdrawal liability has not been satisfied in full, (B) no liability to the PBGC has been incurred by SM&P, which liability has not been satisfied in full, (C) the PBGC has not
 

 
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instituted any proceedings to terminate such plan, (D) no accumulated funding deficiency, whether or not waived, within the meaning of Section 302 of ERISA or Section 412 of the Code has been incurred, and (E) all contributions (including installments) to such plan required by Section 302 of ERISA and Section 412 of the Code have been timely made.
 
(vii)     Except as provided in Section 4(r) of the Disclosure Schedule, there are no plans, arrangements or agreements to which SM&P is a party or by which it is bound and under which as a result of any particular transaction or transactions (including but not limited to the transactions contemplated by this Agreement) any director, officer, employee or other agent of SM&P, or any other party claiming through such a Person, shall or may acquire rights with respect to any SM&P Benefit Plan (including the creation, increase or extension of new or existing rights), become entitled to a distribution or payment with respect to any SM&P Benefit Plan at a date earlier than if such transaction had not occurred, or otherwise receive or become vested in rights and benefits with respect to any SM&P Benefit Plan.  Without limitation of the foregoing, except as set forth in Section 4(r) of the Disclosure Schedule, SM&P is not a party to any agreement with any director, officer, employee or agent of SM&P pursuant to which any such Person will be entitled to any payment by SM&P upon termination of employment following a change in control of SM&P.
 
(viii)    Complete and correct copies of all current documents, including all amendments thereto, with respect to each Employee Benefit Plan have been delivered to the Buyer.
 
(ix)      Except to the extent required under a severance pay plan or under ERISA Section 601, et seq. and Code Section 4980B or applicable state coverage continuation laws, no Employee Benefit Plan provides health or welfare benefits for any retired or former employee or is obligated to provide health or welfare benefits to any active employee following such employee's retirement or other termination of service.
 
(x)      SM&P has complied in all material respects with the provisions of ERISA Section 601, et seq. and Code Section 4980B.
 
(s)    Sufficiency of Assets.  Except as set forth in Section 4(s) of the Disclosure Schedule, the rights, properties and assets owned by or leased or licensed to SM&P include all rights, properties and other assets necessary to permit SM&P to conduct its business in all material respects in the same manner as currently conducted.
 
(t)    Accounts Receivable.  Except as set forth in Section 4(t) of the Disclosure Schedule, all accounts receivable of SM&P that are reflected on the balance sheet of SM&P as of November 30, 2007, included in the SM&P Financial Statements attached as Exhibit A, and the accounting records of SM&P as of the Closing Date represent or will represent valid obligations arising from sales actually made or services actually performed in the Ordinary Course of Business.  SM&P's allowance for uncollectible accounts receivable set forth in such balance sheet was determined in accordance with GAAP consistently applied.  Section 4(t) of the
 

 
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Disclosure Schedule contains a complete and accurate list of all accounts receivable greater than $250,000 as of November 30, 2007 and sets forth the aging of such accounts receivable.
 
(u)    Employees.
 
(i)    Section 4(u) to the Disclosure Schedule contains a complete and accurate list of the following information for each employee of SM&P, including each employee on leave of absence or layoff status:  job title; current compensation paid or payable and any change in compensation since January 1, 2007 or date of hire, if later; vacation accrued; and service credited for purposes of vesting and eligibility to participate under any severance pay, insurance, medical, welfare, vacation, profit-sharing or other employee benefit plan maintained by SM&P or the Seller and available to SM&P employees.  Except as set forth in Section 4(u) of the Disclosure Schedule, SM&P maintains no plans or obligation to pay pension benefits or provide retiree medical or other retiree insurance benefits to any of its current or retired employees.
 
(ii)    No key employee of SM&P listed on Section 4(u)(ii) of the Disclosure Schedule is a party to, or is otherwise bound by, any agreement or arrangement, including any confidentiality, noncompetition or proprietary rights agreement, between such employee or director and any other Person that affects or will affect (A) the performance of his duties as an employee of SM&P, or (B) the ability of SM&P to conduct its business.  To the Seller’s Knowledge, except as set forth in Section 4(u) of the Disclosure Schedule, no officer or other key employee of SM&P intends to terminate his employment with SM&P.
 
(v)    Intellectual Property.
 
(i)    Section 4(v) of the Disclosure Schedule sets forth all of the Intellectual Property owned or used by SM&P.  Except as set forth in Section 4(v) of the Disclosure Schedule, (A) SM&P owns and possesses without restriction as to use, all right, title and interest in and to the Intellectual Property necessary for the operation of SM&P's business as currently conducted; (B) SM&P has not received any notices of invalidity, infringement or misappropriation from any third party with respect to any such Intellectual Property; (C) SM&P has not, infringed upon or misappropriated any Intellectual Property of any third parties in each case other than situations that were resolved without a Material Adverse Effect; and (D) to the Seller's Knowledge, no third party has infringed upon or misappropriated any Intellectual Property of SM&P other than situations that were resolved without a Material Adverse Effect;
 
(ii)    Section 4(v) of the Disclosure Schedule sets forth a true, correct, and complete list of all  Intellectual Property registered in the name of  SM&P and all Intellectual Property for which applications are pending (the “Formal IP”);
 
(iii)    Except as set forth in Section 4(v) of the Disclosure Schedule:  (A) none of the Formal IP in any jurisdiction is the subject of any pending, or to the Seller's Knowledge, threatened, opposition, interference, cancellation or other proceeding before any registration authority in any jurisdiction; (B) each of the Formal IP items have been
 

 
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duly maintained, including without limitation the proper, sufficient and timely submission of all necessary filings and fees; and (C) there are no actions that must be taken within 30 days from the date of this Agreement, including the payment of fees or the filing of documents, for the purposes of obtaining, maintaining, perfecting or renewing any rights in the Formal IP;
 
(iv)     All of the employees, agents or contractors of  SM&P, and any other person who may have created, developed, conceived, reduced to practice or worked on any of the Intellectual Property, whether alone or jointly with Seller or others, have assigned any and all right, title and interest they acquired or may have acquired in and to the Intellectual Property to SM&P.  SM&P has not granted to any third party, and neither the Seller nor any of SM&P's or Seller's respective Affiliates have, any right, claim, title, right of first refusal, interest, permission, license or option in or to any of the  Intellectual Property;
 
(v)       Except as set forth on Section 4(v) of the Disclosure Schedule:  SM&P is not required to pay any royalty, license fee charge or other amount with respect to the Intellectual Property;
 
(vi)      Except as set forth on Section 4(v) of the Disclosure Schedule: SM&P has at all times complied in all material respects with all applicable laws, as well as its own rules, policies, and procedures relating to privacy, data protection, and the collection and use of personal information collected, used or held for use by SM&P in the conduct of SM&P's business.  As of the date hereof, in the past three (3) years, no claims have been asserted or, to the Seller's Knowledge, threatened against SM&P alleging a violation of any Person's privacy or personal information or data rights and the consummation of the transactions contemplated hereby will not breach or otherwise cause any violation of any law, policy or procedure related to privacy, data protection or the collection and use of personal information collected, used or held for use by SM&P in the conduct of SM&P's business.  SM&P takes commercially appropriate measures to ensure that such information is protected against unauthorized access, use, modification or other misuse; and
 
(vii)     SM&P has taken all reasonable steps appropriate to preserve the confidentiality of all trade secrets and know-how included in the Intellectual Property and all such trade secrets and know-how necessary to the operation of the business of SM&P as presently conducted have been adequately documented.  No trade secrets and know-how necessary to the operation of the business of SM&P as presently conducted have been or will be disclosed to any third party and there is no agreement or other arrangement or circumstance under which any third party can require any such disclosure.  Where trade secrets and know-how necessary to the operation of SM&P as presently conducted have been made available to a third party this has been done under a signed confidentiality agreement.
 
(w)    Undisclosed Liabilities.  SM&P and its subsidiaries have no liabilities or obligations of any nature (whether known or unknown and whether absolute, accrued, contingent or otherwise), except for (i) liabilities or obligations reflected or reserved against in the
 

 
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consolidated balance sheet of SM&P as of November 30, 2007, included in the SM&P Financial Statements attached as Exhibit A, (ii) current liabilities incurred in the Ordinary Course of Business since November 30, 2007, (iii) obligations under leases, contracts and other agreements (which agreements are set forth in Section 4(g) of the Disclosure Schedule to the extent they constitute Material Agreements), (iv) liabilities set forth in Section 4(w) of the Disclosure Schedule, and such other liabilities and obligations that would not have, or be reasonably likely to have, a Material Adverse Effect.
 
5.     PRE-CLOSING COVENANTS.  The Parties agree as follows with respect to the period between the execution of this Agreement and the Closing.
 
(a)    General.  Each of the Parties will use its commercially reasonable efforts to take all action and to do all things necessary, proper or advisable to consummate and make effective the transactions contemplated by this Agreement (including satisfaction, but not waiver, of the Closing conditions set forth in Section 7).
 
(b)    Notices and Consents.
 
(i)    The Seller will cause SM&P to give any notices to third parties and will cause SM&P to use its reasonable efforts to obtain any third party consents that the Buyer reasonably may request in connection with the matters referred to in Section 4(c).  Each of the Parties will make (and the Seller will cause SM&P to make) any filings with, and use its reasonable efforts to obtain any authorizations, consents and approvals of, governments and governmental agencies in connection with the matters referred to in Section 3(a)(ii), Section 3(b)(ii) and Section 4(c).
 
(ii)    The Buyer and the Seller shall use commercially reasonable efforts to file, within seven (7) business days after the date of this Agreement, with the United States Department of Justice and the United States Federal Trade Commission the Notification and Report Form required to be filed by them under the HSR Act concerning the transactions contemplated hereby, and shall request early termination of the waiting period under the HSR Act.  The Buyer and the Seller hereby agree that they will promptly comply with any request by the Department of Justice or the Federal Trade Commission for additional documents or information, and will use all commercially reasonable efforts to ensure that such waiting period shall expire, or that clearance will be obtained, as soon as practicable after the execution and delivery of this Agreement.  Each of the Seller and SM&P, on the one hand, and the Buyer, on the other hand, shall promptly inform the other of any material communication received by such party from the Federal Trade Commission, Department of Justice or any other governmental authority regarding any of the transactions contemplated hereby, and of any understandings, undertakings or agreements (oral or written) such party proposes to make or enter into with the Federal Trade Commission, Department of Justice or any other governmental authority in connection with the transactions contemplated hereby.  The fees under the HSR Act shall be paid split equally between the Buyer and the Seller.
 
(c)    Operation of Business.  The Seller will not, without the consent of the Buyer, cause or permit SM&P to engage in any practice, take any action or enter into any transaction
 

 
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outside the Ordinary Course of Business, except as described on Section 5(c) of the Disclosure Schedule.  Without limiting the generality of the foregoing, except as disclosed on Section 5(c) of the Disclosure Schedule, the Seller will not, without the written consent of the Buyer, except as expressly contemplated by this Agreement, cause or permit SM&P to do any of the following:
 
(i)   amend or otherwise change its charter or bylaws;
 
(ii)     declare or pay any dividend, distribution or other payment to the Seller other than in the Ordinary Course of Business, except to eliminate inter-company balances between Seller and SM&P and to transfer cash and cash equivalents excluded from the Working Capital calculation;
 
(iii)   issue, sell, pledge, dispose of, grant, encumber or authorize the issuance, sale, pledge, disposition, grant or encumbrance of (A) any shares of capital stock of any class of SM&P or any options, warrants, convertible securities or other rights of any kind to acquire any shares of such capital stock or any other ownership interest (including any phantom interest) in SM&P or (B) any assets and properties material to SM&P;
 
(iv)   (A) acquire (including by merger, consolidation or acquisition of stock or assets) any corporation, partnership or other business organization or any division thereof, (B) incur any indebtedness for borrowed money or issue any debt securities or assume, guarantee or endorse, or otherwise as an accommodation become responsible for, the obligations of any person, or make any loans or advances, except borrowings in the Ordinary Course of Business pursuant to any existing credit agreements or pursuant to intercompany loan agreements with the Seller, or (C) enter into or amend any contract, agreement, commitment or arrangement with respect to any matter set forth in this paragraph (iv);
 
(v)    (A) increase the compensation payable to, or grant any severance or termination pay to, its officers, employees, directors or consultants, except pursuant to existing contractual arrangements or existing compensation plans and except for spot awards not to exceed $100,000 in the aggregate, (B) enter into any employment, consulting or severance agreement with any director, officer or other employee or consultant of SM&P outside the Ordinary Course of Business or which provides for annual compensation in excess of $100,000, or (C) establish, adopt, enter into or amend any bonus, profit sharing, thrift, compensation, stock option, restricted stock, pension, retirement, deferred compensation, employment, termination, severance or other plan, agreement, trust, fund, policy or arrangement for the benefit of any director, officer, employee or consultant;
 
(vi)    change any material accounting practice for GAAP or Tax purposes, unless required by a change in accounting rules or applicable law;
 
(vii)  amend in any material respect any Material Agreement, or terminate any Material Agreement before the expiration of the term thereof;
 
(viii)  pay, discharge or satisfy any liability or obligation (whether accrued, absolute, contingent or otherwise) in excess of $50,000 other than the payment, discharge
 

 
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or satisfaction, in the Ordinary Course of Business, of liabilities or obligations shown or reflected on the SM&P Financial Statements or incurred in the Ordinary Course of Business;
 
(ix)       permit or suffer any assets (whether real, personal or mixed, tangible or intangible) to be subjected to any Security Interest, other than Permitted Encumbrances, except in the Ordinary Course of Business;
 
(x)       permit the waste of any of its properties or assets, whether or not covered by insurance;
 
(xi)      cancel, forgive or compromise any debt or obligation due to SM&P, except in the Ordinary Course of Business;
 
(xii)     dispose of any records related to its assets or business at any time earlier than it would have done consistent with past practices; or
 
(xiii)    agree to do any of the foregoing, whether or not in writing.
 
            The Buyer shall designate a person who will be available during normal business hours to consult with the Seller and SM&P regarding actions for which the Buyer's consent is required and endeavor to promptly respond to all requests of the Seller and SM&P for consents required by this Section.
 
(d)    Full Access.  The Seller will permit, and will cause SM&P to permit, representatives of the Buyer to have full access during normal business hours, and in a manner so as not to interfere with the normal business operations of SM&P, to all premises, properties, personnel, books, records (including tax records), contracts and documents of or pertaining to SM&P.  Any information obtained by the Buyer and its employees, representatives, consultants, attorneys, agents, lenders and other advisors under this Section 5(d) shall be subject to the confidentiality and use restrictions contained in (i) that certain nondisclosure agreement between the Seller and Kohlberg Management IV, L.L.C. dated October 17, 2007, (ii) that certain nondisclosure agreement between the Seller and Kohlberg Management IV, L.L.C. dated January 9, 2008 and (iii) that certain nondisclosure agreement between Seller and CCG Securities LLC dated October 15, 2007 (collectively, the “Confidentiality Agreements”).
 
(e)    Notice of Developments.
 
(i)    Each Party will give prompt written notice to the other of any material adverse development causing a breach of any of its own representations and warranties in Section 3 or 4.  Subject to Section 5(e)(ii), no disclosure by any Party pursuant to this Section 5(e), however, shall be deemed to amend or supplement the Disclosure Schedule or to prevent or cure any misrepresentation or breach of warranty.  Without limiting the generality of the foregoing, Buyer will immediately notify Seller of any proposed material amendments or modifications or termination of any of the Financing Commitments.
 

 
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(ii)    If the Seller notifies the Buyer that an item was omitted from the Disclosure Schedule, and Buyer concurs, in its sole discretion, that the omission did not prejudice the Buyer (and only in such event), such omitted item shall be added to the Disclosure Schedule and will be deemed to have qualified the representations and warranties in Section 3 or 4 and to have cured any misrepresentation or breach of warranty that might otherwise have existed hereunder by reason of the omission of such item from the Disclosure Schedule.
 
(f)    Parent Guaranties.  Each of the Parties will use its reasonable efforts to obtain the termination and release of any existing guaranties of SM&P's obligations by the Seller or any of its subsidiaries, including in the case of the Buyer agreeing to replace such guaranties with a guarantee from Buyer or an Affiliate of the Buyer or other reasonable credit support.  
 
(g)    Termination of Affiliate Transactions.  Seller shall terminate, or cause SM&P to terminate, as of the Closing Date each of the Related Party Agreements (and all rights, obligations and liabilities arising from the Related Party Agreements), except each of the agreements listed on Section 5(g) of the Disclosure Schedule.
 
(h)    Exclusivity.  Until this Agreement is terminated by its terms, the Seller shall not (nor shall the Seller cause or permit any Person acting on behalf of the Seller, SM&P or the Seller's Affiliates to), (i) solicit, initiate or encourage the submission of any proposal or offer from any Person (including any of them) relating to any (A) liquidation, dissolution or recapitalization of, (B) merger or consolidation with or into, (C) acquisition or purchase of assets (other than in the Ordinary Course of Business) of or any equity interest in or (B) similar transaction or business combination involving SM&P or (ii) participate in any discussions or negotiations regarding, furnish any information with respect to, assist or participate in, or facilitate in any other manner any effort or attempt by any other Person to do or seek any of the foregoing.  The Seller agrees that it will discontinue immediately (and will cause SM&P or any Person acting on behalf of the Seller, SM&P, or the Seller's Affiliates to discontinue immediately) any negotiations or discussion with respect to any of the foregoing.  Until this Agreement is terminated by its terms, the Seller shall notify the Buyer immediately if any Person makes any proposal, offer, inquiry or contact with respect to any of the foregoing.
 
6.     POST-CLOSING COVENANTS.  The Parties agree as follows with respect to the period following the Closing.
 
(a)    General.  In case at any time after the Closing any further action is necessary to carry out the purposes of this Agreement, each of the Parties will take such further action (including the execution and delivery of such further instruments and documents) as any other Party reasonably may request, all at the sole cost and expense of the requesting Party (unless the requesting Party is entitled to indemnification therefor under Section 8).
 
(b)    Litigation Support.  In the event and for so long as any Party actively is contesting or defending against any third party action, suit, proceeding, hearing, investigation, charge, complaint, claim or demand in connection with (i) any transaction contemplated under this Agreement or (ii) any fact, situation, circumstance, status, condition, activity, practice, plan, occurrence, event, incident, action, failure to act or transaction on or before the Closing Date
 

 
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involving SM&P, each of the other Parties shall cooperate with it and its counsel in the defense or contest, make available their personnel and provide such testimony and access to their books and records as shall be reasonably necessary in connection with the defense or contest and without interfering with such other Party's ability to conduct its business, all at the sole cost and expense of the contesting or defending Party (unless the contesting or defending Party is entitled to indemnification therefor under Section 8).
 
(c)    Transition.  The Seller and its Affiliates will not take any action that is designed or intended to have the effect of discouraging any lessor, licensor, customer, supplier, employee or other business associate of SM&P (other than the Seller and its Affiliates) from maintaining the same business relationships with SM&P after the Closing as it maintained with SM&P before the Closing.
 
(d)    Access to Information and Cooperation.  After the Closing, the Buyer shall afford to the Seller and its representatives and advisors such access during normal business hours with reasonable notice to the books, records and personnel of SM&P and to such other information, and shall furnish such cooperation relating to SM&P, as the Seller shall reasonably request for financial reporting and accounting matters, the preparation and filing of any tax applications or returns, the defense of tax claims and related purposes.  The Buyer shall cause SM&P to preserve all tax and accounting records of SM&P for a period of seven years following the Closing.  In addition, the Seller shall afford the Buyer, and its respective representatives and advisors, similar access to any books, records and files retained by the Seller relating to the business of SM&P.
 
(e)    Noncompete.
 
(i)    For a period of four (4) years after the Closing (the “Noncompete Period”), neither the Seller nor any of its Affiliates shall engage or participate, directly or indirectly (as owner, partner, stockholder or in any other capacity) in the utility line locating and marking business as such business was being conducted by SM&P at the Closing Date in any state in which SM&P was at the Closing Date conducting such business; provided, however, that the Seller and its Affiliates may continue to engage in such business for the Seller and its Affiliates (but not for unrelated third parties).  Notwithstanding the foregoing, this provision shall not prohibit the Seller from acquiring another corporation that conducts a minimal amount of utility line locating and marking.
 
(ii)    The Seller agrees that, during the Noncompete Period, the Seller (A) shall not, and shall cause its Affiliates not to, directly or indirectly, contact, approach or solicit (other than through advertising in a newspaper or other publication not directed primarily to employees of SM&P) for the purpose of offering employment to or hiring (whether as an employee, consultant, agent, independent contractor or otherwise) any person employed by SM&P at any time within two (2) years prior to the Closing Date or during the Noncompete Period, without the prior written consent of the Buyer, which shall not be unreasonably withheld or delayed, and (B) shall not induce or attempt to induce, and shall cause its Affiliates not to induce or attempt to induce, any customer or other business relation of SM&P to terminate its business relationship with SM&P or to materially reduce its business with SM&P.  The term “indirectly” as used in this
 

 
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Section is intended to mean any acts authorized or directed by or on behalf of the Seller or any Person controlled by the Seller.
 
(iii)    The Seller agrees that the Buyer would suffer irreparable harm from a breach by such Seller of any of the covenants or agreements contained in this Section 6(e).  In the event of an alleged or threatened breach by the Seller of any of the provisions of this Section 6(e), the Buyer or its successors or assigns may, in addition to all other rights and remedies existing in its favor, apply to any court of competent jurisdiction for specific performance and/or injunctive or other relief in order to enforce or prevent any violations of the provisions hereof.  To the extent of any breach of this Section 6(e), the Noncompete Period shall automatically be extended by the length of such breach.
 
(iv)    If, at the time of enforcement of any of the provisions of this Section 6(e), a court holds that the restrictions stated therein are unreasonable under the circumstances then existing, the Parties agree that the maximum period, scope or geographical area reasonable under such circumstances shall be substituted for the stated period, scope or area.  The Seller acknowledges that, without provisions contained in this Section 6(e), the Buyer would have not entered into this Agreement.
 
(f)    Employee Matters.
 
(i)    Continuation of Compensation and Benefits.  For a period of one year after the Closing Date, the Buyer shall maintain, or shall cause SM&P to maintain, base salary, wages, compensation levels (including bonus and other incentive compensation) and Employee Benefit Plans for the benefit of the employees and former employees of SM&P, which, in the aggregate, are at least equivalent to the base salary, wages, compensation levels and SM&P Benefit Plans provided to the employees and former employees of SM&P on the date of this Agreement, subject to promotions, demotions and layoffs in the Ordinary Course of Business.
 
(ii)    Service Credit.  The Buyer shall provide, or shall cause SM&P to provide, each employee or former employee of SM&P with credit for all service with SM&P for purposes of determining eligibility to participate, vesting or qualification or eligibility for any benefit or privilege (including vacation) based on length of service under any Buyer Benefit Plan (but excluding determining benefit accruals under any Buyer Benefit Plan that is a defined benefit plan as defined in Section 3(35) of ERISA).
 
(iii)    Welfare Benefit Plan Obligations.  With respect to any Buyer Employee Welfare Benefit Plan covering any employee or former employee (and covered spouse or dependant) of SM&P after the Closing Date, the Buyer shall (i) waive all limitations as to preexisting conditions, exclusions and waiting periods, and (ii) provide each such employee or former employee (and any covered spouse or dependent) with credit for any co-payments and deductibles paid prior to the Closing Date in satisfying any applicable deductible or out-of-pocket requirements under any Buyer Benefit Plan in which such employee or former employee is eligible to participate after the Closing Date.
 

 
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(iv)    Third Party Rights. Nothing contained in this Agreement (including, without limitation, this Section 6(f)) shall (A) amend, or be deemed to amend, any Employee Benefit Plan, (B) provide any person not a party to this Agreement with any right, benefit or remedy with regard to any Employee Benefit Plan or a right to enforce any provision of this Agreement, or (C) limit in any way the Buyer's ability to amend or terminate any particular Employee Benefit Plan at any time.
 
7.     CONDITIONS TO OBLIGATION TO CLOSE.
 
(a)    Conditions to Obligation of the Buyer.  The obligation of the Buyer to consummate the transactions to be performed by it in connection with the Closing is subject to satisfaction of the following conditions:
 
(i)      the representations and warranties set forth in Section 3(a) and Section 4 above shall be true and correct in all material respects at and as of the Closing Date; provided, however, that if any such representation or warranty is already qualified by materiality or Material Adverse Effect, for purposes of determining whether this condition has been satisfied, such representation or warranty as so qualified shall be true and correct in all respects;
 
(ii)     the Seller shall have performed and complied with all of its covenants hereunder in all material respects through the Closing;
 
(iii)    there shall not be any injunction, judgment, order, decree, ruling or charge in effect preventing consummation of any of the transactions contemplated by this Agreement;
 
(iv)    any applicable waiting period under the HSR Act, including any extension, shall have expired or shall have been earlier terminated;
 
(v)     the Seller shall have delivered to the Buyer a certificate to the effect that each of the conditions specified in the foregoing clauses (i) through (iii) is satisfied;
 
(vi)     the Seller shall have delivered to the Buyer the certificate called for by Section 9(b);
 
(vii)    the Buyer shall have received (A) all the stock records, corporate books and records of SM&P in the possession of SM&P or Seller, except that notwithstanding the foregoing limitation, with respect to the Board of Directors and stockholder minutes of SM&P the Buyer shall have received all such Board of Director and stockholder minutes of SM&P from January 28, 2002 through the Closing Date and (B) the resignations, effective as of the Closing Date, of all of the officers and directors of SM&P;
 
(viii)    the Seller shall have delivered to the Buyer an opinion of the Seller's legal counsel dated as of the Closing Date as to the matters set forth as Exhibit B to this Agreement;
 

 
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(ix)       the Seller shall have delivered to the Buyer certified copies of the resolutions of the Seller's Board of Directors approving the transactions contemplated by this Agreement;
 
(x)        the Buyer shall have received a certificate of the Secretary of State of the State of Indiana certifying that SM&P is duly formed under the laws of such state and in good standing with the Secretary of State as of a date not more than five (5) days prior to the Closing Date;
 
(xi)       the Buyer shall have received a certificate of the Secretary of State of each state in which SM&P is authorized to do business certifying that Seller is authorized to do business in such State and in good standing with the Secretary of State as of a date not more than five days prior to the Closing Date;
 
(xii)      the Seller shall have obtained the consents set forth in Section 7(a)(xii) of the Disclosure Schedule in form and substance reasonably acceptable to the Buyer;
 
(xiii)     the Buyer shall have had an opportunity to contact customers of SM&P listed in Section 7(a)(xiii) of the Disclosure Schedule, in coordination with Seller’s representatives and shall not have advised the Seller that the Buyer received any indication that any customer or customers intend to terminate or materially reduce its or their business with SM&P where such action would have, or be reasonably likely to have, a Material Adverse Effect;
 
(xiv)      the Buyer shall have obtained all necessary third-party financing required in order to consummate the transactions contemplated hereby and to meet the ongoing working capital requirements of the business of SM&P;
 
(xv)       all liens (other than Permitted Encumbrances) on the assets of SM&P shall have been released in a manner reasonably satisfactory to the Buyer;
 
(xvi)      the Buyer shall have received an estoppel certificate from each of the landlords of the Leased Real Property identified on Section 7(a)(xvi) of the Disclosure Schedule substantially in the form of Exhibit C hereto;
 
(xvii)     the Buyer shall have received from SM&P an affidavit complying with the Foreign Investment in Real Property Tax Act;
 
(xviii)    the Buyer shall have received from SM&P a payoff letter or payoff letters, in form and substance reasonably satisfactory to the Buyer, executed by each Person to which SM&P is obligated with respect to any Indebtedness, together, as applicable, with original UCC termination statements and other lien releases terminating all liens securing such amounts (or such payoff letters shall include authority or commitment to file such statements and releases in form and substance reasonably satisfactory to the Buyer); and
 
(xix)     the Buyer shall have received such other documents as the Buyer may reasonably request for the purpose of facilitating the consummation or performance of any of the transactions contemplated by this Agreement.
 

 
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The Buyer may waive any condition specified in this Section 7(a) if it executes a writing so stating at or before the Closing.
 
(b)    Conditions to Obligation of the Seller.  The obligation of the Seller to consummate the transactions to be performed by it in connection with the Closing is subject to satisfaction of the following conditions:
 
(i)     the representations and warranties set forth in Section 3(b) above shall be true and correct in all material respects at and as of the Closing Date; provided, however, that if any such representation or warranty is already qualified by materiality or Material Adverse Effect, for purposes of determining whether this condition has been satisfied, such representation or warranty as so qualified shall be true and correct in all respects;
 
(ii)     the Buyer shall have performed and complied with all of its covenants hereunder in all material respects through the Closing;
 
(iii)    there shall not be any injunction, judgment, order, decree, ruling, or charge in effect preventing consummation of any of the transactions contemplated by this Agreement;
 
(iv)    any applicable waiting period under the HSR Act, including any extension, shall have expired or shall have been earlier terminated;
 
(v)     the Buyer shall have delivered to the Seller  a certificate to the effect that each of the conditions specified in the foregoing clauses (i) through (iii) is satisfied; and
 
(vi)    all guaranties of SM&P's obligations by the Seller or any of its subsidiaries that are set forth in Section 7(b)(vi) of the Disclosure Schedule shall have been terminated and released.
 
The Seller may waive any condition specified in this Section 7(b) if it executes a writing so stating at or before the Closing.
 
8.     REMEDIES FOR BREACHES OF THIS AGREEMENT.
 
(a)    Survival of Representations and Warranties.  All of the representations and warranties of the Seller contained in Section 3(a) shall survive the Closing indefinitely.  All of the representations and warranties of the Buyer contained in Section 3(b) shall survive the Closing indefinitely.  All of the representations and warranties of the Seller contained in Section 4 shall survive the Closing and continue in full force and effect for a period of twelve months thereafter, whereupon they shall terminate; provided, however that (i) and the representations and warranties of the Seller contained in Sections 4(a) (Organization, Qualification and Corporate Power), 4(b) (Capitalization) shall survive the Closing indefinitely and (ii) the representations and warranties of the Seller contained in Sections 4(e) (Title to Personal Property), 4(i) (Environmental Matters), 4(l) (Taxes) and 4(r) (Employee Benefits) shall survive the Closing until the expiration of the statute of limitations applicable thereto.
 

 
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(b)    Indemnification Provisions for Benefit of the Buyer.
 
(i)    Subject to the limitations in Section 8(b)(ii), the Seller agrees to indemnify the Buyer, SM&P and any of their respective Affiliates, directors, officers, employees and agents (collectively, the “Buyer Indemnified Parties”) from and against any Adverse Consequences any Buyer Indemnified Party suffers as a result of the breach of any of the Seller's representations, warranties, covenants and other agreements contained herein or in any certificate delivered in connection herewith (without regard to any materiality or Material Adverse Effect qualifiers contained in any such representation, warranty, covenant or agreement), provided that (A) such Adverse Consequences arising from any individual claim exceed the Claim Deductible, and (B) in the case of breaches of representations and warranties contained in Section 4, the Buyer makes a written claim for indemnification against the Seller pursuant to Section 11(g) within the applicable survival period.
 
(ii)    Notwithstanding Section 8(b)(i), the Seller shall have no obligation under Section 8(b)(i) to indemnify the Buyer Indemnified Parties from and against any Adverse Consequences until the aggregate of the Adverse Consequences for all claims otherwise required to be indemnified by the Seller under Section 8(b)(i) exceeds $750,000 (the “Deductible”).  After the aggregate of the Adverse Consequences for all claims otherwise required to be indemnified by the Seller under Section 8(b)(i) exceeds the Deductible, the Seller shall indemnify the Buyer Indemnified Parties for all Adverse Consequences in excess of the Deductible, up to a maximum aggregate indemnity under this Agreement of $7,000,000 (the “Cap”).  Notwithstanding the foregoing, neither the Deductible nor the Cap shall apply to claims for indemnification for a breach of the representations and warranties of the Seller contained in (A) Section 3(a) or (B) Sections 4(a) (Organization, Qualification and Corporate Power), 4(b) (Capitalization), 4(e) (Title to Personal Property), 4(l) (Taxes) and 4(r) (Employee Benefits).
 
(c)    Indemnification Provisions for Benefit of the Seller.  The Buyer agrees to indemnify the Seller and any of its respective Affiliates, directors, officers, employees and agents (collectively, the “Seller Indemnified Parties”) from and against the entirety of any Adverse Consequences the Seller suffers as a result of the breach of any of the Buyer's representations, warranties and covenants contained herein (without regard to any materiality or Material Adverse Effect qualifiers contained in any such representation, warranty and covenant).
 
(d)    Matters Involving Third Parties.
 
(i)    If any third party notifies any Party (the “Indemnified Party”) with respect to any matter (a “Third Party Claim”) that may give rise to a claim for indemnification against any other Party (the “Indemnifying Party”) under this Section 8, the Indemnified Party shall promptly (and in any event within five (5) business days after receiving notice of the Third Party Claim) notify each Indemnifying Party thereof in writing; provided, however, that no delay on the part of an Indemnified Party in notifying the Indemnifying Party shall relieve the Indemnifying Party of any of its obligations hereunder unless and then solely to the extent that the Indemnifying Party is irrevocably prejudiced by such
 

 
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delay.  The notice shall include a description of the Third Party Claim and copies of all documents relating to the claim.
 
(ii)    Any Indemnifying Party will have the right to assume and thereafter conduct the defense of the Third Party Claim with counsel of its choice reasonably satisfactory to the Indemnified Party; provided that the Indemnifying Party will not consent to the entry of any judgment or enter into any settlement with respect to the Third Party Claim without the prior written consent of the Indemnified Party (not to be withheld unreasonably) unless the judgment or proposed settlement fully releases such Indemnified Party and involves only the payment of money damages that are covered in full by the indemnity and does not impose an injunction or other equitable relief upon the Indemnified Party and is subject to confidentiality provisions acceptable to the Indemnified Party (which approval will not be unreasonably withheld by the Indemnified Party).
 
(iii)    Unless and until an Indemnifying Party assumes the defense of the Third Party Claim as provided in Section 8(d)(ii), the Indemnified Party may defend against the Third Party Claim in any manner it reasonably may deem appropriate.
 
(iv)    In no event will the Indemnified Party consent to the entry of any judgment or enter into any settlement with respect to the Third Party Claim without the prior written consent of each Indemnifying Party, which consent shall not be unreasonably withheld.
 
(e)    No Contribution.  No Indemnifying Party or any of its employees or agents shall have any right of contribution, right of indemnity or other right or remedy against SM&P in connection with any indemnification obligation or any other liability to which she, he or it may become subject under or in connection with this Agreement.
 
(f)    Exclusive Remedies.  Except as provided in Section 9, the rights, remedies and obligations of the Parties under this Section 8 shall be the exclusive rights, remedies and obligations of the Parties for any breach or default in connection with the transactions contemplated by this Agreement.  
 
9.     TAX MATTERS.
 
(a)    Scope of Tax Indemnity Provisions.  In the case of any indemnity claim for Taxes for a Pre-Closing Period, the indemnity obligations of the Seller, and the rights of the Buyer with respect to indemnification, shall be governed by this Section and not by Section 8 hereof (regardless of whether the Taxes for which indemnity is being claimed result from a breach of a representation in Section 4(l) hereof).  The indemnity obligations of the Seller under this Section shall survive the Closing until thirty (30) days after the expiration of the statute of limitation to which the Tax liabilities relate.
 
(b)    Allocation of Liability for Taxes.  The Seller shall be liable for, and shall indemnify, defend and hold the Buyer and its Affiliates, including SM&P harmless from and against, (i) any and all Taxes together with any costs, expenses, losses or damages, including reasonable expenses of investigation and attorneys' and accountants' fees and expenses, arising
 

 
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out of or incident to the determination, assessment or collection of such Taxes (collectively, “Tax Losses”) imposed on or with respect to SM&P, or its respective assets, operations or activities for any Pre-Closing Period (including, but not limited to, Taxes resulting by reason of the several liability of SM&P pursuant to Treasury Regulation Section 1.1502-6 or any analogous state, local or foreign law by reason of SM&P having been a member of any consolidated, combined or unitary group on or prior to the Closing Date) and (ii) any Tax Losses resulting from the breach of the Seller's representations and warranties set forth in Section 4(l) or covenants set forth in this Section 9, but only to the extent that such Taxes have not been included in the final determination of Working Capital. The Seller shall deliver to the Buyer, pursuant to Section 7(a)(v), at closing a certificate setting forth the accrual for current Taxes (excluding any accrual for deferred taxes), as of the Closing Date, on the balance sheet of SM&P on the Closing Date.  For purposes of this Article 9, the phrase “accrual for current Taxes” includes Taxes which are directly payable by SM&P and Taxes which represent amounts (whether computed pursuant to a Tax sharing or Tax reimbursement agreement or otherwise) owing to an Affiliate of SM&P with respect to Taxes paid by such Affiliate with respect to the activities, business or operations of SM&P.  The Buyer shall be liable for, and shall indemnify, defend and hold the Seller harmless from and against, any and all Taxes imposed on or with respect to SM&P, or its respective operations, ownership, assets or activities for any Post-Closing Period.
 
(c)    Proration of Taxes.
 
(i)    Method of Proration.  Tax items shall be apportioned between Pre-Closing and Post-Closing Periods based on a closing of the books and records of the relevant entity or entities as of the Closing Date (provided that (i) any Tax item incurred by reason of the transactions occurring on or before the Closing Date as contemplated by this Agreement, including any Tax item resulting from a prior intercompany transaction that has been deferred and that will be taxed as a result of the changes in ownership contemplated by this Agreement, shall be treated as occurring in a Pre-Closing Period and (ii) depreciation, amortization and depletion for any Straddle Period shall be apportioned on a daily pro rata basis).  Notwithstanding anything to the contrary in the preceding sentence, the parties agree that for U.S. federal income Tax purposes, Tax items for any Straddle Period shall be apportioned between Pre-Closing Periods and Post-Closing Periods in accordance with U.S. Treasury Regulation Section 1.1502-76(b)(2)(i), which regulations shall be reasonably interpreted by the parties in a manner intended to achieve the method of apportionment described in the preceding sentence.  Notwithstanding anything to the contrary herein, any franchise Tax paid or payable with respect to SM&P shall be allocated to the taxable period during which the income, operations, assets or capital comprising the base of such Tax is measured, regardless of whether the right to do business for another taxable period is obtained by the payment of such franchise Tax.
 
(ii)    No Contrary Elections.  The Seller and the Buyer will not exercise any option or election (including any election to ratably allocate a Tax year's items under Treasury Regulation Section 1.1502-76(b)(2)(ii)) to allocate Tax items in a manner inconsistent with Section 9(c)(i) hereof.
 

 
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(d)    Refunds of Taxes; Amended Returns; Carryovers.
 
(i)    Refunds.  Subject to Section 9(d)(iii) hereof, if the Buyer receives a Tax refund with respect to Taxes arising in a Pre-Closing Period, the Buyer shall pay, within ninety (90) days following the receipt of such Tax refund, the amount of such Tax refund to the Seller to the extent such Tax refund has not been included in the final determination of Working Capital.  If the Seller receives a Tax refund with respect to Taxes arising in any Post-Closing Tax Period, within ninety (90) days following the receipt of such Tax refund, the Seller will pay the amount of such Tax refund to the Buyer.
 
(ii)    Transaction Related Tax Reductions.  Any Tax refunds, deductions, credits of Taxes or other reductions in Taxes paid or payable to or by SM&P or the consolidated group of which it is a member resulting from compensatory payments made by SM&P arising in connection with the transactions contemplated by this Agreement and outside of the Ordinary Course of Business (“Compensatory Tax Benefit”), shall be for the account of the Buyer and shall be treated for purposes of this Section 9 as not relating to Pre-Closing Tax Periods.  The Seller shall pay to Buyer an amount equal to any Compensatory Tax Benefit within 90 days of the receipt of any such Compensatory Tax Benefit.
 
(iii)    Amended Tax Returns.
 
(A)    Subject to Section 9(d)(iv) hereof, any amended Tax Return or claim for Tax refund for any Pre-Closing Period other than a Straddle Period shall be filed, or caused to be filed, only by the Seller.  The Seller shall not, without the prior written consent of the Buyer, make or cause to be made, any such filing, to the extent such filing, if accepted, reasonably might change the Tax liability of the Buyer for any Tax Period.
 
(B)    An amended Tax Return or claim for Tax refund for any Straddle Period shall be filed by the party responsible for filing the original Tax Return hereunder if either the Buyer or the Seller so request, except that such filing shall not be done without consent (which shall not be unreasonably withheld or delayed) of the Buyer (if request is made by the Seller) or of the Seller (if request is made by the Buyer).
 
(C)    Any amended Tax Return or claim for Tax refund for any Post-Closing Period other than a Straddle Period shall be filed, or caused to be filed, only by the Buyer, who shall not be obligated to make (or cause to be made) such filing.  The Buyer shall not, without the prior written consent of the Seller (which consent shall not be unreasonably withheld or delayed) file, or cause to be filed, any amended Tax Return or claim for Tax refund for any Post-Closing Period to the extent that such filing, if accepted, reasonably might change the Tax liability of the Seller for any Pre-Closing Period.
 

 
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(iv)    Carrybacks.  If any Tax loss or credit with respect to SM&P arising in a Post-Closing Period may be carried back and included in any Tax Return filed or caused to be filed by the Seller with respect to SM&P for any Pre-Closing Period, the Buyer may elect (at its expense) to carry back such Tax items (subject to Seller's consent, which consent shall not be unreasonably withheld or delayed), but only if SM&P cannot elect to waive the carryback.  In such case, the Seller shall pay to the Buyer an amount equal to the Tax Benefit resulting from such carryback of Tax loss or credit, provided that the Seller shall not be required to file any carryback claim unless the Buyer so requests in writing and agrees to pay the reasonable expenses related to the claim for refund.
 
(e)    Preparation and Filing of Tax Returns.
 
(i)    Seller's Responsibilities.  The Seller shall have the right and obligation to timely prepare and file, and cause to be timely prepared and filed, when due, any Tax Return that is required to include the operations, ownership, assets or activities of SM&P for Tax Periods ending on or before the Closing Date and for Tax Periods beginning before and ending after the Closing Date for which a consolidated, combined or unitary Tax Return is filed that includes SM&P for the period prior to and including the Closing Date (other than a combined or unitary Tax Return with respect to which SM&P is the parent or reporting corporation). The Seller shall be responsible for reimbursing the Buyer for Taxes of SM&P relating to (a) taxable periods ending on or prior to the Closing Date, (b) any Straddle Period to the extent attributable to the portion of such Straddle Period ending on the Closing Date except in either case, to the extent such Taxes were included in the final determination of Working Capital or (c) income included in a consolidated, unitary or combined Tax Return of Seller or any Affiliate of Seller.
 
(ii)    Buyer's Rights and Responsibilities.  The Buyer shall have the right and obligation to timely prepare and file, or cause to be timely prepared and filed, when due, all Tax Returns that are required to include the operations, ownership, assets or activities of SM&P for any Tax Periods ending after the Closing Date (including all Straddle Period Tax Returns), except for consolidated, combined or unitary Tax Returns described in Section 9(e)(i).
 
(iii)    Preparation of Tax Returns.
 
(A)    The Seller shall prepare and provide to the Buyer such Tax information as is reasonably requested by the Buyer with respect to the operations, ownership, assets or activities of SM&P or for Pre-Closing Periods to the extent such information is relevant to any Tax Return which the Buyer has the right and obligation hereunder to file.
 
(B)    The Seller shall, on the one hand, or the Buyer shall, on the other, with respect to any Tax Return that such Party is responsible hereunder for preparing and filing, or causing to be prepared and filed, make such Tax Return and related work papers available for review by the other Party and its advisors if the Tax Return (i) is with respect to Taxes for which the other Party or a member of its Affiliated Group may be liable hereunder, or (ii) claims Tax Benefits that
 

 
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the other party or a member of its Affiliated Group is entitled to receive hereunder. The filing Party shall use its reasonable best efforts to make Tax Returns available for review as required under this paragraph sufficiently in advance of the due date for filing such Tax Returns to provide the non-filing Party and its advisors with a meaningful opportunity to analyze and comment on such Tax Returns and have such Tax Returns modified before filing, accepting the position of the filing party unless such position is contrary to the provisions of Section 9(e)(iv) hereof.
 
(iv)    Consistency of Accounting Method.  Any Tax Return that includes or is based on the operations, ownership, assets or activities of SM&P for any Pre-Closing Period, and any Tax Return that includes or is based on the operations, ownership, assets or activities of SM&P for any Post-Closing Period to the extent the items reported on such Tax Return might reasonably increase any Tax liability of the Seller for any Pre-Closing Period or any Straddle Period shall be prepared in accordance with past Tax accounting practices as used with respect to the Tax Returns in question (unless such past practices are no longer permissible under the Applicable Tax Law), and to the extent any items are not covered by past practices (or in the event such past practices are no longer permissible under the Applicable Tax Law), in accordance with reasonable Tax accounting practices selected by the filing Party with respect to such Tax Return under this Agreement with the consent (not to be unreasonably withheld or delayed) of the non-filing Party.
 
(f)    Tax Controversies; Assistance and Cooperation.
 
(i)    Notice.  In the event any Tax Authority informs the Seller (or its Affiliates), on the one hand, or the Buyer or SM&P (or their Affiliates), on the other, of any notice of proposed audit, claim, assessment or other dispute concerning an amount of Taxes with respect to which the other Party may incur liability hereunder, the Party so informed shall promptly notify the other Party of such matter.  Such notice shall contain factual information (to the extent known) describing any asserted Tax liability in reasonable detail and shall be accompanied by copies of any notice or other documents received from any Tax authority with respect to such matter.  If an indemnified Party receives written notice of an asserted Tax liability with respect to a matter for which it is to be indemnified hereunder and such Party fails to provide the indemnifying Party prompt notice of such asserted Tax liability, then (A) if the indemnifying Party is precluded from contesting the asserted Tax liability in any forum as a result of the failure to give prompt notice, the indemnified Party shall have an obligation to indemnify the indemnifying Party for Taxes arising out of such asserted Tax liability, and (B) if the indemnifying Party is not precluded from contesting the asserted Tax liability in any forum, but such failure to provide prompt notice results in a monetary detriment to the indemnifying Party, then any amount that the indemnifying Party is otherwise required to pay the indemnified Party pursuant to this Agreement shall be reduced by the amount of such detriment.
 
(ii)    Control Rights.  The Party who files the relevant Tax Return under this Section shall, at its expense, control any audits, disputes, administrative, judicial or other
 

 
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proceedings related to Taxes with respect to which either Party may incur liability hereunder.  Subject to the preceding sentence, in the event an adverse determination may result in the non-filing Party having responsibility for any amount of Taxes under this Section, the non-filing Party shall be entitled to fully participate in that portion of the proceedings relating to the Taxes with respect to which it may incur liability hereunder.  For purposes of this Section 9(f), the term “participation” shall include (A) participation in conferences, meetings or proceedings with any Tax Authority, the subject matter of which includes an item for which such Party may have liability hereunder, (B) participation in appearances before any court or tribunal, the subject matter of which includes an item for which a party may have liability hereunder, and (C) with respect to the matters described in the preceding clauses (A) and (B), participation in the submission and determination of the content of the documentation, protests, memorandum of fact and law, briefs and the conduct of oral arguments and presentations.
 
(iii)    Consent to Settlement.  SM&P, the Buyer and the Seller and their respective Affiliates shall not agree to settle any Tax liability or compromise any claim with respect to Taxes, which settlement or compromise may affect the liability for Tax hereunder (or right to Tax Benefit) of the other Party under this Section, without such other Party's consent (which consent shall not be unreasonably withheld or delayed).
 
(iv)    Assistance and Cooperation.  The Seller, on the one hand, and the Buyer, on the other, shall cooperate (and cause their Affiliates to cooperate) with each other and with each other's agents, including accounting firms and legal counsel, in connection with Tax matters relating to SM&P, including (A) preparation and filing of Tax Returns, (B) determining the liability and amount of any Taxes due or the right to and amount of any refund of Taxes, (C) examinations of Tax Returns, and (D) any administrative or judicial proceeding in respect of Taxes assessed or proposed to be assessed.  Such cooperation shall include each Party making all information and documents in its possession relating to SM&P available to the other party.  The parties shall retain all Tax Returns, schedules and work papers, and all material records and other documents relating thereto, until the expiration of the applicable statute of limitations (including, to the extent notified by any party, any extension thereof) of the Tax Period to which such Tax Returns and other documents and information relate.  Each of the Parties shall also make available to the other Party, as reasonably requested and available, personnel (including officers, directors, employees and agents) responsible for preparing, maintaining, and interpreting information and documents relevant to Taxes, and personnel reasonably required as witnesses or for purposes of providing information or documents in connection with any administrative or judicial proceedings relating to Taxes.
 
(v)    Payment.  Promptly after the extent of the liability of the indemnified Party with respect to an indemnified Tax claim shall be established by the final judgment or decree of a court or a final and binding settlement with a governmental authority having jurisdiction thereof, the indemnifying Party shall pay to the indemnified Party the amount of any Tax Losses the indemnified Party may become entitled to by reason of the provisions of this Section 9.
 

 
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(g)    Termination of Tax Allocation Agreements.  As of the Closing Date, the Seller shall cause all Tax allocation, Tax sharing, Tax reimbursement, Tax indemnification and similar arrangements or arrangements between the Affiliated Group that includes the Seller on the one hand, and SM&P on the other (collectively, the “Tax Allocation Agreement”), to be extinguished and terminated with respect to SM&P.  Notwithstanding the foregoing, prior to the Closing Date, SM&P shall be entitled to make payments to the Seller pursuant to the existing Tax allocation agreement among the Affiliated Group that includes the Seller and SM&P, and after the Closing, the Seller shall be entitled to receive from SM&P (and the Buyer shall cause SM&P to make) payments for Taxes paid by the Seller on behalf of SM&P pursuant to the existing Tax Allocation Agreement with respect to any Pre-Closing Period but only to the extent such Taxes were included in the final determination of Working Capital.  Moreover, prior to the Closing Date, the Seller and SM&P shall be entitled to forgive, without payment, any amounts owed by the Seller to SM&P under the existing Tax Allocation Agreement relating to any Pre-Closing Period.  
 
(h)    Indemnification for Post-Closing Transactions.  The Buyer agrees to indemnify the Seller for any additional Tax owed by the Seller (including Tax owed by the Seller due to this indemnification payment) resulting from any transaction not in the Ordinary Course of Business occurring on the Closing Date after the Buyer's purchase of the SM&P Shares.
 
(i)    Post-Closing Transactions Not in the Ordinary Course.  The Buyer and the Seller agree to report all transactions not in the Ordinary Course of Business occurring on the Closing Date, after the Buyer's purchase of the SM&P Shares, on the Buyer's federal income Tax Return to the extent permitted by Treas. Reg. Section l.1502-76(b)(l)(ii)(B).
 
(j)    Survival.  Anything to the contrary in this Agreement notwithstanding, the representations, warranties, covenants, agreements, rights and obligations of the parties hereto with respect to any Tax matter covered by this Agreement shall survive the Closing and shall not terminate until 30 days after the expiration of the statute of limitations (including extensions) applicable to such Tax matter.
 
(k)    Conflicts.  To the extent any provision of this Agreement is inconsistent with the provisions of this Section 9, the provisions of Section 9 shall control; provided, however, any amounts due or owing pursuant to this Section 9 will not be considered in calculating limits on the Seller's obligations under Section 8(b).  Any payments pursuant to this Section 9 will be considered an adjustment to the Final Adjusted Purchase Price.
 
10.     TERMINATION.
 
(a)    Termination of Agreement.  The Parties may terminate this Agreement as provided below:
 
(i)    The Buyer and the Seller may terminate this Agreement by mutual written consent at any time before the Closing;
 
(ii)    The Buyer may terminate this Agreement by giving written notice to the Seller at any time before the Closing (A) in the event the Seller has breached any representation, warranty or covenant contained in this Agreement and such breach(es)
 

 
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has, or would be reasonably likely to have, a Material Adverse Effect, the Buyer has notified the Seller of the breach, and the breach has continued without cure for a  period of 10 business days after the notice of breach; or (B) if the Closing shall not have occurred on or before May 15, 2008, by reason of the failure of any condition precedent under Section 7(a) (unless the failure results primarily from the Buyer itself breaching any representation, warranty or covenant contained in this Agreement); and
 
(iii)    The Seller may terminate this Agreement by giving written notice to the Buyer at any time before the Closing (A) in the event the Buyer has breached any representation, warranty or covenant contained in this Agreement in any material respect, the Seller has notified the Buyer of the breach, and the breach has continued without cure for a period of 10 business days after the notice of breach, (B) if any of the Financing Commitments has been materially modified or amended or terminated such that Buyer would not be reasonably likely to be able to finance the transactions contemplated hereby and Buyer shall not have obtained replacement financing reasonably satisfactory to the Seller within 10 business days thereafter, or (C) if the Closing shall not have occurred on or before May 15, 2008, by reason of the failure of any condition precedent under Section 7(b) (unless the failure results primarily from the Seller itself breaching any representation, warranty or covenant contained in this Agreement).
 
(b)    Effect of Termination.  If any Party terminates this Agreement pursuant to Section 10(a), all rights and obligations of the Parties hereunder shall terminate without any liability of any Party to any other Party (except for any liability of any Party then in breach); provided that the confidentiality provisions and limitations on use contained in the Confidentiality Agreements and the provisions of Section 11 shall survive termination.
 
11.     MISCELLANEOUS.
 
(a)    Press Releases and Public Announcements.  No Party shall issue any press release or make any public announcement relating to the subject matter of this Agreement before the Closing without the prior written approval of the Buyer and the Seller; provided, however, that any Party may make any public disclosure it believes in good faith is required by applicable law or any listing or trading agreement concerning its publicly traded securities (in which case the disclosing Party will use its reasonable efforts to advise the other Party and review the contents of the press release or public announcement with the other Party a reasonable time before making the disclosure).
 
(b)    No Third Party Beneficiaries.  This Agreement shall not confer any rights or remedies upon any Person other than the Parties and their respective successors and permitted assigns.
 
(c)    Entire Agreement.  This Agreement (including the Exhibits and Schedules identified herein) and the Confidentiality Agreements constitute the entire agreement between the Parties and supersede any prior understandings, agreements or representations by or between the Parties, written or oral, to the extent they relate to the subject matter hereof.  The Exhibits and Schedules identified in this Agreement are incorporated herein by reference and made a part hereof.
 

 
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(d)    Succession and Assignment.  This Agreement shall be binding upon and inure to the benefit of the Parties named herein and their respective successors and permitted assigns.  No Party may assign either this Agreement or any of its rights, interests or obligations hereunder without the prior written approval of the other party; provided, that the Buyer may assign its rights, interests and obligations hereunder to any Affiliate of the Buyer or to its financing sources, as security for any obligations arising in connection with its financing, without, in either case, the prior written consent of the Seller.
 
(e)    Counterparts; Facsimile.  This Agreement may be executed in one or more counterparts, each of which shall be deemed an original but all of which together will constitute one and the same instrument.  This Agreement may be executed by facsimile signature.
 
(f)    Headings.  The Section headings contained in this Agreement are inserted for convenience only and shall not affect in any way the meaning or interpretation of this Agreement.
 
(g)    Notices.  All notices, requests, demands, claims and other communications hereunder will be in writing.  Any notice, request, demand, claim or other communication hereunder shall be deemed duly given if (and then two (2) business days after) it is sent by registered or certified mail, return receipt requested, postage prepaid, and addressed to the intended recipient as set forth below:
 

If to the Seller:
                    
                    The Laclede Group, Inc.
                    720 Olive Street
                    St. Louis, Missouri 63101
                    Attention: Mark C. Darrell
 
with a copy, which shall not constitute notice, to:
 
                    Thompson Coburn LLP
                    One US Bank Plaza
                    St. Louis, Missouri 63101
                    Attention: Thomas A. Litz
 
If to the Buyer:
 
                    Kohlberg & Co., L.L.C.
                    111 Radio Circle
                    Mt. Kisco, NY 10549
                    Attention: Gordon H. Woodward
                                Benjamin Mao
 
with a copy, which shall not constitute notice, to:
 
O’Melveny & Myers LLP
Times Square Tower
 
43
7 Times Square
New York, New York 10036
Attention:  James Moriarty

Any Party may send any notice, request, demand, claim or other communication hereunder to the intended recipient at the address set forth above using any other means (including personal delivery, expedited courier, messenger service, facsimile transmission, telex, ordinary mail or electronic mail), but no such notice, request, demand, claim or other communication shall be deemed to have been duly given unless and until it actually is received by the intended recipient.  Any Party may change the address to which notices, requests, demands, claims and other communications hereunder are to be delivered by giving the other Party notice in the manner herein set forth.
 
(h)    Governing Law.  This Agreement shall be governed by and construed in accordance with the domestic laws of the State of Missouri without giving effect to any choice or conflict of law provision or rule (whether of the State of Indiana or any other jurisdiction) that would cause the application of the laws of any jurisdiction other than the State of Missouri.
 
(i)    Amendments and Waivers.  No amendment of any provision of this Agreement shall be valid unless the same shall be in writing and signed by the Buyer and the Seller.  No waiver by any Party of any default, misrepresentation or breach of warranty or covenant hereunder, whether intentional or not, shall be deemed to extend to any prior or subsequent default, misrepresentation or breach of warranty or covenant hereunder or affect in any way any rights arising by virtue of any prior or subsequent such occurrence.
 
(j)    Severability.  Any term or provision of this Agreement that is invalid or unenforceable in any situation in any jurisdiction shall not affect the validity or enforceability of the remaining terms and provisions hereof or the validity or enforceability of the offending term or provision in any other situation or in any other jurisdiction.
 
(k)    Expenses.  Each Party will bear its own costs and expenses (including legal fees and expenses) incurred in connection with this Agreement and the transactions contemplated hereby.  The Seller hereby agrees to pay any and all costs and expenses (including legal fees and expenses) incurred or otherwise owing by SM&P that have been incurred (or are otherwise owing) through the Closing Date in connection with this Agreement and the transactions contemplated hereby except to the extent that such costs and expenses have been included in the final determination of Working Capital.  Notwithstanding the foregoing to the contrary, in no event shall any such cost or expense of SM&P be deemed to include any cost or expense initiated at the direction of the Buyer or any of its Affiliates (e.g., any cost or expense incurred in connection with the Financing Commitments).
 
(l)    Construction.  The Parties have participated jointly in the negotiation and drafting of this Agreement.  In the event an ambiguity or question of intent or interpretation arises, this Agreement shall be construed as if drafted jointly by the Parties, and no presumption or burden of proof shall arise favoring or disfavoring any Party by virtue of the authorship of any of the provisions of this Agreement.  Any reference to any federal, state, local or foreign statute
 
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or law shall be deemed also to refer to all rules and regulations promulgated thereunder, unless the context requires otherwise.  The word “including” shall mean “including, without limitation.”
 
[Signature Page Follows]

 
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IN WITNESS WHEREOF, the Parties hereto have executed this Agreement on the date first above written.
 

 
 
THE LACLEDE GROUP, INC.
     
 
By:
 
 
Name:
 
 
Title:
 
     
     
     
 
STRIPE ACQUISITION, INC.
     
 
By:
 
 
Name:
 
 
Title:
 




 
46
 
 

EX-10.4 5 ex10-4.htm EXHIBIT 10.4 ex10-4.htm

Exhibit 10.4

 SUPPLEMENTAL PENSION AGREEMENT
With Kenneth J. Neises


This Agreement is entered into by and between Laclede Gas Company (the “Company”) and Kenneth J. Neises (“Neises”).

RECITALS

WHEREAS, Neises is a key employee of the Company and was to retire on his mandatory retirement date of November 1, 2005; and

WHEREAS, in recognition of the value of Neises’ services to the Company the Board adopted resolutions on November 18, 2004 and October 26, 2007 allowing him to work beyond his mandatory retirement date under the Retirement Plan up to December 1, 2009;

NOW, THEREFORE, in consideration of the mutual promises contained in this Agreement, the parties agree as follows:

 
Article I – Definitions

1.1
Code” means the Internal Revenue Code of 1986, as amended.
   
1.2
   
1.3
“Moody’s Corporate Bond Average Rate” means the “Published Monthly Average Composite Yield on Seasoned Corporate Bonds” published by Moody’s Investor’s Service, Inc. available at http://www.naic.org/research_moody.htm or a successor site.
   
1.4
Plans” means the Retirement Plan and the SERP.
   
1.5
“Retirement Plan” means the Employees’ Retirement Plan of Laclede Gas Company as amended from time to time and any other qualified defined benefit pension plan of the Company.
   
1.6
“SERP” means the Laclede Gas Company Supplemental Retirement Benefit Plan as amended from time to time and any successor plan.

 
 
 
 

 
Article II – Nature of the Agreement

2.1
Overview of Benefits Provided by this Agreement.  This Agreement provides for a deferred compensation benefit to Neises as described in more detail in Article III (“Supplemental Pension Benefit”).  The Agreement does not modify Neises’ benefits under the Plans.
   
2.2
Nature of Contract.  Neises’ employment with the Company has been and will continue to be at will.  Nothing contained in this Agreement shall be construed to be a contract of employment for any term, nor as conferring upon Neises the right to continue in the employ of the Company in his present capacity or any other capacity.  Nothing contained in this Agreement shall be construed to preclude termination of his employment at any time.  It is expressly understood by the parties that this Agreement relates exclusively to compensation for Neises’ services and is not an employment contract.

 
Article III – Calculation of Pension Benefit Amount

3.1
Supplemental Pension Benefit Formula.  Upon the earliest to occur of Neises’ death, Disability, or retirement, such date being known as the Calculation Date, the Supplemental Pension Benefit under this Agreement shall be calculated and shall be in an amount equivalent to:
   
(A+B+C) – D
 
 
where A, B, C, and D are as follows:
   
 
A.
= Neises’ monthly accrued benefit under the Plans calculated as if he had retired on November 1, 2005 converted to a lump amount calculated using the PBGC rate in effect on November 1, 2005 of 2.5% and other factors and formulas effective under the Plans for retirements on November 1, 2005;
       
 
B.
= The difference between (i) the monthly accrued benefit calculated in A. above, and (ii) the monthly accrued benefit calculated as if he had retired on November 1, 2007; with the difference between (i) and (ii) then converted to a lump sum amount calculated using the lower of the PBGC rate in effect on November 1, 2007 of 3.25% or the PBGC rate in effect for retirements on the Calculation Date, and other factors and formulas effective under the Plans for retirements on November 1, 2007;
       
 
C.
= The difference between (I) the monthly accrued benefit calculated in B.(ii), and (II) the monthly accrued benefit calculated on the Calculation Date; with the difference between (I) and (II) then converted to a lump sum amount calculated using the factors and formulas effective under the Plans for retirements on the Calculation Date; and
       
 
D.
= Neises’ monthly accrued benefit under the Plans converted to a lump sum amount calculated using the factors and formulas effective under the Plans for retirements on the Calculation Date.


 
 
 
- 2 - -
 
 



   No Supplemental Pension Benefit shall accrue under this Agreement on and after the Calculation Date.
   
3.2
Payment of Supplemental Pension Benefit  The Supplemental Pension Benefit shall be payable:
   
 
If payable due to Neises’ Disability or death, in a lump sum to Neises or his beneficiary, as applicable, 30 days after the date of his Disability or death; or
       
 
If payable due to Neises’ retirement, on the date that is six months after the date of his retirement, or such earlier date as may be allowed by law.  From the date of his retirement to the date of actual payment, the Supplemental Pension Benefit shall earn simple interest at rate equal to the Moody’s Corporate Bond Average Rate as in effect on the date of his retirement.

Article IV – General Provisions

4.1
General Creditor Status.  Neises’ claim against the Company under this Agreement shall be that of an unsecured general creditor of the Company.  Any benefit payable under the Agreement shall represent an unfunded and unsecured promise to pay by the Company.  The Company shall not be obligated to set aside, earmark, or escrow any funds or other assets to satisfy its obligations under this Agreement.
   
4.2
Anti-assignation.  The interests of Neises and his beneficiaries under this Agreement are not subject to the claims of their creditors and may not be voluntarily or involuntarily sold, transferred, alienated, assigned, pledged, anticipated, or encumbered.  Any attempt by Neises to transfer, alienate, assign, pledge, anticipate, encumber, charge or otherwise dispose of any right to benefits payable hereunder shall be void.  The Company may cancel and refuse to pay any portion of a benefit that is sold, transferred, alienated, assigned, pledged, anticipated or encumbered.
       
 
Distribution pursuant to a domestic relations order of all or any portion of the Supplemental Pension Benefit may be paid to an Alternate Payee (as defined in Section 414(p) of the Code) who is a former spouse in an amount specified in such domestic relations order in a lump-sum cash payment as soon as administratively feasible after it is determined that the order is a domestic relations order (as defined in Section 414(p)(1)(B) of the Code).
   
4.4
Amendment.  The provisions of this Agreement may be amended or waived only with the prior written consent of each of Neises and the Company.
   
4.5
Controlling State Law.  The laws of the State of Missouri shall be controlling in all matters relating to this Agreement.
   
4.6
Severability.  In case any provision of this Agreement shall be held illegal or invalid for any reason, such illegality or invalidity shall not affect the remaining provisions of the


 
 
 
- 3 - -
 
 


 
Agreement, and the Agreement shall be construed and enforced as if such illegal and invalid provisions had never been set forth.
   
4.7
Full Discharge of Obligation.  Payment of the Supplemental Pension Benefit shall constitute (i) payment in full of the benefits due Neises and his beneficiaries under this Agreement and (ii) fulfillment of all of the Company’s obligations under this Agreement.
       
4.8
Tax Withholding.  All distributions under this Agreement, to the extent required by law, shall be subject to withholding of federal, state and local taxes.
   
4.9
Code Section 409A.  Notwithstanding any other provision hereof, this Agreement is intended to comply with Section 409A and shall at all times be interpreted in accordance with such intent.  To the extent that any provision of the Agreement violates Code Section 409A such that amounts would be taxable to Neises prior to payment or otherwise subject to penalties under Code Section 409A, such provision shall be automatically reformed or stricken to preserve the intent hereof.
   
   
   
  IN WITNESS WHEREOF, the Company and Neises have executed this Agreement this 7th day of March, 2008.



 

 
LACLEDE GAS COMPANY.
   
 
By  /s/ D. H. Yaeger
 
Title: Chief Executive Officer



   
   
 
/s/ Kenneth J. Neises
 
Kenneth J. Neises
   







 
 
 
- 4 - -
 
 

EX-10.5 6 ex10-5.htm EXHIBIT 10.5 ex10-5.htm


Exhibit 10.5
Contract  #3147
AMENDED AND RESTATED
STORAGE SERVICE AGREEMENT
FOR RATE SCHEDULE FSS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

This STORAGE SERVICE AGREEMENT, hereinafter referred to as "Agreement," made and entered into by and between CenterPoint Energy - Mississippi River Transmission Corporation, a Delaware corporation, hereinafter called "MRT," and Laclede Gas Company, a Missouri corporation, hereinafter called "Customer."

In consideration of the mutual covenants herein contained, the parties hereto agree that MRT shall provide natural gas storage service for Customer, on a firm basis, and Customer shall furnish, or cause to be furnished, to MRT natural gas for such storage during the term hereof, at the rates and on the terms and conditions hereinafter provided.

1)
TERM*
       
 
Effective Date:
Originally May 1, 2002, as amended and restated effective April 1, 2008 
 
Primary Term End Date:
April 30, 2013
       
 
*     Pursuant to Section 2.7, Rate Schedule FSS, MRT and Customer have agreed to an Effective Date and a Primary Term End Date other than the
       beginning of the injection season and the end of the withdrawal season, respectively.
       
 
Evergreen?
Yes  [ X ]          No  [    ]
   
 
After Primary Term End Date, this Agreement shall continue to be in effect unless and until terminated by either MRT or Customer by written notice or electronically via the Internet as permitted or requested by MRT, to the other delivered at least one (1) year prior to the date of intended termination.
       
2)
QUANTITIES
 
       
 
Maximum Stored Quantity (MSQ):                                                      23,550,243 Dth
 
(Based on a heat content of 1,020 Btu per Cubic Foot)
       
 
Maximum Daily Withdrawal Quantity (MDWQ):                                        410,231 Dth
       
3)
RATE
 
     
 
Service hereunder shall be provided pursuant to Rate Schedule FSS.  Customer shall pay, or cause to be paid, to MRT each month for all services provided hereunder the maximum applicable rate and any other charges specified in MRT's FERC Gas Tariff, Third Revised Volume No. 1, as on file and in effect from time to time, for services rendered hereunder, unless otherwise agreed (either in writing or electronically via the Internet as required by MRT) by MRT and Customer in an Exhibit A, or other format provided for in the Tariff, in effect during the term of this Agreement or in a capacity release award.
       
5)
ADDRESSES
 
     
 
For Notices to Customer:
For Bills to Customer:
 
Laclede Gas Company
Laclede Gas Company
 
Attn:  Steven F. Mathews
Attn: Gas Accounting
 
720 Olive Street
720 Olive Street, 13th  Floor
 
St. Louis, MO 63101
St. Louis, MO 63101
 
Telephone:  (314) 516-8585
Telephone:  (314) 516-8595
 
Facsimile:    (314) 421-1979
Facsimile:    (314) 241-2278
 
E-Mail:  smathews@lacledegas.com
 
     
 
For Notices to MRT:
For Payments to MRT:
 
1600 S. Brentwood Blvd., Suite 590
P.O. Box 203293
 
St. Louis, MO 63144
Houston, TX 77216-3293
 
Facsimile:  (314) 991-7600
 
 
Page 1 of 4
 
 
 
 
Contract #3147
AMENDED AND RESTATED
STORAGE SERVICE AGREEMENT
FOR RATE SCHEDULE FSS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY




   
For Wire Transfer Payment to MRT:
 
MRT Nominations (other than electronic):
Mississippi River Transmission
 
Client Services
Chase Bank of Texas
 
Facsimile:  (318) 429-3298
ABA No. 113000609
   
Account No.
 
MRT Pipeline Operations:
 
 
System Control Department
 
 
1600 S. Brentwood Blvd., Suite 590
 
 
St. Louis, MO 63144
 
 
Telephone: (314) 991-9900
 
 
E-Mail:  mrtconsole@centerpointenergy.com
 

 
IN WITNESS WHEREOF, the parties have executed this Agreement as of the last date shown below.


CENTERPOINT ENERGY - MISSISSIPPI RIVER
LACLEDE GAS COMPANY
 
TRANSMISSION CORPORATION
       
           
           
By:
/s/ Robert Trost
 
By:
/s/ Kenneth J. Neises
 
Name
Robert Trost
 
Name:
Kenneth J. Neises
 
Title
Division Vice President – Marketing MRT
 
Title:
Executive Vice President
 
           
Date:
March 18, 2008
 
Date:
March 18, 2008
 
           





Page 2 of 4
 
 
 
 
Contract #3147
AMENDED AND RESTATED
STORAGE SERVICE AGREEMENT
FOR RATE SCHEDULE FSS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY


GENERAL TERMS AND CONDITIONS

1)
Upon termination hereof for whatever reason, Customer agrees to stop delivering gas to MRT for storage hereunder.  In addition, upon termination of this Agreement, Customer agrees that it will thereafter make no further demand for service hereunder and MRT agrees that it will make no further demand for the continuation of services or any payment related thereto, other than payments which are due with respect to any services previously provided.  Customer agrees to cooperate with and assist MRT in obtaining whatever regulatory approvals and authorizations, if any, as are necessary or appropriate in view of such termination and abandonment of service hereunder.
   
2)
Termination of this Agreement shall not relieve either party of any obligation that might otherwise exist to correct any volume imbalance hereunder (including withdrawal of stored quantities) nor relieve Customer of its obligation to pay any monies due hereunder to MRT.
   
3)
In accordance with the terms and conditions of Section 17 of the General Terms and Conditions of MRT's FERC Gas Tariff, Third Revised Volume No. 1 (General Terms and Conditions), if Customer fails to pay within thirty (30) days after payment is due all of the amount of any bill for service rendered by MRT hereunder, MRT, upon ten (10) days' written notice to Customer, may suspend further injections and/or withdrawals of gas until such past due amount is paid, or satisfactory credit arrangements have been made in accordance with Section 5 of the General Terms and Conditions.  If Customer fails to pay or make satisfactory credit arrangements within such ten (10) day notice period, MRT, in addition to any other remedy it may have hereunder, may, upon thirty (30) days' written notice to Customer, terminate this Agreement and cease further injections and/or withdrawals of gas on behalf of Customer.
   
4)
Service hereunder shall be provided pursuant to Rate Schedule FSS of MRT's FERC Gas Tariff, Third Revised Volume No. 1.  Customer will provide Fuel Use and LUFG.
   
5)
This Agreement shall be subject to the provisions of the applicable rate schedule as well as the General Terms and Conditions set forth in MRT's Tariff, as on file and in effect from time to time, and such provisions are incorporated herein by this reference.  Any curtailment of storage service hereunder shall be in accordance with the priorities set out in MRT's General Terms and Conditions.  To the extent not inconsistent with effective law, MRT shall have the right to determine the priority and/or scheduling of the storage service under this Agreement and to revise the priority and/or scheduling of this storage service from time to time.
   
6)
MRT shall have the right at any time and from time to time to file and place into effect unilateral changes or modifications in the rates and charges, and other terms and conditions of service hereunder, as set forth in the applicable rate schedule and in the General Terms and Conditions, in accordance with the Natural Gas Act or other applicable law.
   
7)
In the event that MRT places on file with the Commission another rate schedule which may be applicable to service rendered hereunder, then MRT, at its option, may, from and after the effective date of such rate schedule, utilize such rate schedule in the performance of this Agreement.  Such rate schedule or superseding rate schedule(s) and any revisions thereof which shall be filed and become effective shall apply to and be a part of this Agreement.  MRT shall have the right to propose, file and make effective with the Commission, or other body having jurisdiction, changes and revisions of any effective rate schedule(s) and/or General Terms and Conditions, or to propose, file, and make effective superseding rate schedules and/or General Terms and Conditions, for the purpose of changing the rates, charges, and other provisions thereof effective as to Customer.
   
8)
Except as provided in this paragraph, this Agreement shall not be assigned by Customer in whole or in part without MRT’s prior written or electronic consent, which consent shall not be unreasonably withheld.  Customers under Rate Schedule FSS may release their capacity consistent with the terms and conditions of the applicable rate schedule and the General Terms and Conditions of MRT’s Tariff.  Additionally, Customer may request that MRT consent to Customer’s assignment of this Agreement, in whole, to an entity affiliated with Customer.  For firm contracts, MRT will only consent to assignment of the contract to a Customer’s affiliate, subject to the assignee’s satisfaction of the criteria in Section 5.4(k), GT&C, in the situation in which, after Customer obtains the contract, a corporate reorganization results in a transfer to an affiliate of the function for which the capacity was obtained.  Any entity that succeeds by purchase, merger, consolidation or otherwise to the properties of Customer, substantially as an entirety, shall be entitled to the rights and shall be subject to the obligations of its predecessors in title under this Agreement.  Subject to the above, the respective rights and obligations of the parties under this Agreement shall extend to and be binding upon their heirs, successors, assigns and legal representatives.  In addition to all other  rights  and  remedies, MRT may terminate the Agreement immediately if it is assigned by Customer without MRT’s consent, whether


Page 3 of 4
 
 
 
 
Contract #3147
AMENDED AND RESTATED
STORAGE SERVICE AGREEMENT
FOR RATE SCHEDULE FSS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

GENERAL TERMS AND CONDITIONS
(Continued)


 
the assignment or contract be voluntary or by operation of law or otherwise.  Subject to the above, the respective rights and obligations of the parties under the Agreement shall extend to and be binding upon their heirs, successors, assigns and legal representatives.
   
9)
Any notice, statement, or bill provided for in this Agreement shall be in writing, or if MRT’s Tariff requires, via electronic means and shall be considered as duly delivered when hand-delivered, telecopied, or when received by the other party if mailed by United States mail, postage prepaid, to the addresses specified herein (unless and until either party notifies the other, in writing, of a change in its address).
   
10)
Each party shall notify the other in writing of the name, address, telephone number and telecopy number and e-mail address of the person or persons who shall have authority to act for such party in connection with this Agreement, and operating notices shall thereafter be served upon such person or persons.
   
11)
This Agreement constitutes the entire agreement between the parties and no waiver, representation or agreement, oral or otherwise, shall affect the subject matter hereof unless and until such waiver, representation or agreement is reduced to writing (or, if MRT permits or requires, otherwise memorialized via electronic means) and executed by authorized representatives of the parties.  No waiver by either Customer or MRT of any one or more defaults by the other in performance of any of the provisions of the Agreement shall operate or be construed as a waiver of any other existing or future default or defaults, whether of a like or of a different character.
   
12)
THE INTERPRETATION AND PERFORMANCE OF THE AGREEMENT SHALL BE IN ACCORDANCE WITH THE LAWS OF MISSOURI, EXCLUDING CONFLICTS OF LAW PRINCIPLES THAT WOULD REQUIRE THE APPLICATION OF THE LAWS OF A DIFFERENT JURISDICTION.
   
13)
Exhibit A attached hereto is incorporated into the Agreement in its entirety.
   
14)
This Agreement amends and restates the currently effective Storage Service Agreement between the parties.
   
15)
Pursuant to Section 5.1(a), Rate Schedule NNT, of MRT’s Tariff, Customer shall have the option to reduce its FSS capacity in proportion to Customer’s reduction of the MDQ under FTS Contract  3310, Section 18 of the General Terms and Conditions, between MRT and Customer.  Customer must exercise its option within thirty (30) days after service commences to the Bypassing Customer over its direct connection with MRT, with the reduction of FSS capacity becoming effective reasonably concurrent with the reduction of FTS capacity, taking into consideration that any gas that Customer may be required to remove from storage as a result of the FSS capacity reduction must be undertaken in a reasonable manner and in a reasonable time period.
   
16)
Pursuant to Section 15.3, General Terms and Conditions, of MRT’s Tariff, the parties agree that Customer has the Right of First Refusal (ROFR).  If Customer chooses to exercise its ROFR, it shall do so by following the procedures applicable to the exercise of a ROFR provided for in the Tariff.



Page 4 of 4
 
 
 
 


Contract #3147
AMENDED AND RESTATED
STORAGE SERVICE AGREEMENT
FOR RATE SCHEDULE FSS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

Page 1 of 2
EXHIBIT A
 
Customer agrees to pay the rates specified on this Exhibit A for performance of certain gas transportation service under the Agreement specified above.  These rates are applicable only in accordance with the following:

RATES AND APPLICABILITY:

(a)
General:  In consideration for Customer's continuing compliance with the provisions of the Transportation Service Agreement ("Agreement") specified above, the transportation rates and charges as defined below for the specified services provided under the Agreement only apply to receipts from, and subsequent deliveries to, the Points of Receipt and Delivery, quantities and/or time periods described herein and to reserved capacity necessary to effect such service.  In addition to any rate or amount referred to herein (including discounted rates, Negotiated Rates, overrun rates and maximum tariff rates), Customer shall pay any applicable charges, penalties, surcharges, fees, taxes, settlements and/or direct billed amounts provided for in MRT's Tariff.  In any event, the rate in any month shall never be below MRT's applicable minimum tariff rate for a discount rate transaction.  For a Negotiated Rate transaction, the rate in any month shall never be below MRT's applicable minimum tariff rate, unless MRT otherwise agrees.  MRT shall not be responsible for the payment and satisfaction of any taxes assessed or levied on the receipt, transmission (and any activities in connection therewith), delivery, use and/or consumption with respect to gas delivered or received by Customer, unless MRT agrees otherwise.

(b)
Inability to Collect Negotiated Rates:    If this Exhibit A covers a Negotiated Rate transaction, and MRT is unable to collect Negotiated Rates due to a change in Commission policy or rejection of the transaction by the Commission prior to or during the term of such transaction, then, unless the parties agree otherwise, Customer shall pay the maximum tariff rate for the services.  In such event, MRT shall notify Customer in writing of the requirement to pay maximum tariff rates and, if the maximum tariff rates are greater than the Negotiated Rates under such transaction, Customer shall have no more than thirty (30) days from the date of such notification to give notice in writing of termination of the applicable Agreement, with such termination to be effective no later than the end of the month following the month in which such termination notice is received.
   
(c) Description of Rate:                         Negotiated Rate  [    ]                           Discounted Rate [ X ]     (Check one)                                 
 
        (i) 
Base Rate:  Customer’s rate for service shall be the maximum Base Tariff Rate(s) set forth in MRT’s Tariff from time to time; provided, however, that during the Term of this Agreement, Customer’s Base Rate(s) shall not  exceed the maximum Base Rate Deliverability, Capacity, and Injection/Withdrawal Charges  set forth on Twenty-Seventh  Revised Sheet No. 8 (effective November 1, 2007), or if as a result of a rate design change in a Section 4 or 5 rate proceeding, the equivalent of the maximum Base Rate Deliverability, Capacity, and Injection/Withdrawal Charge(s) set forth on Twenty-Seventh Revised Sheet No. 8 when computed at an assumed 100% load factor as follows: $0.3121.
   
        (ii) 
Surcharges: All applicable Rate Schedule FSS surcharges, penalties, charges, fees, taxes, settlements, direct billed amounts and Fuel Use and LUFG retentions.

 
(d)             Term of Rate: Begin Date(s): April 1, 2008
     
 
End Date(s):
April 30, 2013 and continuing thereafter unless and until terminated by either MRT or Customer by written notice or electronically via the Internet as permitted or required by MRT, to the other delivered at least one (1) year prior to the date of the intended termination.

(e)
Authorized Overrun:  For discounted rate transactions, any authorized overrun quantities shall be at the assumed 100% load factor derivative of the Base Rate(s) set forth in (c) above, plus all applicable Rate Schedule FSS surcharges, penalties, and Fuel Use and LUFG retentions.



 
 
 
 


Contract #3147
AMENDED AND RESTATED
STORAGE SERVICE AGREEMENT
FOR RATE SCHEDULE FSS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY


Page 2 of 2
EXHIBIT A
(continued)


(f)
Rate-Related Provisions:

 
(i)
Consideration for Rate Granted:  MRT agrees to the rates specified in this Exhibit A in exchange for Customer's agreement to forego credits or other benefits to which Customer would otherwise be entitled under the Agreement, but only to the extent such credits or benefits would result in a greater economic benefit over the term of this Exhibit A than that represented by the agreed-upon rate.  Accordingly, unless MRT otherwise agrees, Customer will not receive credits (with the exception of (1) penalty revenue credits provided pursuant to Section 34 of the General Terms and Conditions of MRT's Tariff, and (2) capacity release credits) from rates, refunds or other revenues collected by MRT or Customer if to do so would effectively result in a lower rate or greater economic benefit to Customer; provided, however, that (I) for a Customer taking service under a discount or recourse rate agreement, the rate in any month shall never be above MRT's applicable maximum tariff rate, and (II) MRT and a Customer taking service under a Negotiated Rate agreement can agree pursuant to Section 14.2 of the General Terms and Conditions of MRT's Tariff that MRT will retain some or all of the capacity release credits to the extent those credits exceed the amount of the Customer's invoiced demand component.  If the parties' agreement to the foregoing is determined invalid or if Customer seeks to obtain credits or benefits inconsistent therewith, unless MRT otherwise agrees, it will have the right to immediately terminate or modify any provisions of this Exhibit A that would allow Customer to pay amounts less than the maximum applicable tariff rate.

 
(ii)
Regulatory Authority:  This Exhibit A is subject to Section 30 of the General Terms and Conditions of MRT's Tariff.  MRT and Customer hereby acknowledge that this Exhibit A is subject to all valid and applicable federal and local laws and to the orders, rules and regulations of any constituted federal or local regulatory body or governmental authority having jurisdiction.  Any provision of this Exhibit A which is determined by any court or regulatory body having jurisdiction to be invalid or unenforceable will be ineffective to the extent of such determination only, without invalidating, or otherwise affecting the validity of, the remaining provisions.  Except as otherwise provided in subsection (b) above, unless the parties agree otherwise, if MRT  reasonably determines that a federal or local law, or order, rule or regulation of any governmental authority having or asserting jurisdiction (1) requires performance by MRT that is inconsistent with the terms of this Exhibit A, or (2) conditions or prohibits the granting of selective discounts or other rates specified in paragraph (d) of this Exhibit A, then MRT and Customer shall promptly take all reasonable actions in good faith to enter into alternative arrangements that will secure to the maximum extent practicable for each party all of the benefits of the transaction set out in this Agreement; provided however, that MRT shall not be required to enter into or continue arrangements that would result in a greater economic detriment to MRT than existed prior to the regulatory event or change.

Executed by a duly authorized representative of each party hereto, in the space provided below:


CENTERPOINT ENERGY - MISSISSIPPI RIVER
LACLEDE GAS COMPANY
 
TRANSMISSION CORPORATION
       
           
           
By:
/s/ Robert Trost
 
By:
/s/ Kenneth J. Neises
 
Name
Robert Trost
 
Name:
Kenneth J. Neises
 
Title
Division Vice President – Marketing MRT
 
Title:
Executive Vice President
 
           
Date:
March 18, 2008
 
Date:
March 18, 2008
 
           



 
 
 
 

EX-10.6 7 ex10-6.htm EXHIBIT 10.6 ex10-6.htm

Exhibit 10.6
Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

This Transportation Service Agreement (hereinafter referred to as “Agreement”) is made and entered into by and between CenterPoint Energy - Mississippi River Transmission Corporation, a Delaware corporation, hereinafter called “MRT,” and Laclede Gas Company, a Missouri corporation, hereinafter called “Customer.”

In consideration of the mutual covenants herein contained, the parties hereto agree that MRT shall transport for Customer, on a firm basis, and Customer shall furnish, or cause to be furnished, to MRT natural gas for such transportation during the term hereof, at the rates and on the terms and conditions hereinafter provided.

1)
TERM:
       
 
Effective Date:
Originally May 1, 2002, as amended and restated effective April 1, 2008
       
 
Primary Term End Date:
April 30, 2013
       
   
Evergreen:
Yes     [ X ]              No [    ]    If Yes, describe:
After the Primary Term End Date, this Agreement shall continue to be in effect thereafter unless and until terminated by either MRT or Customer by written notice or electronically via the Internet as permitted or required by MRT, to the other delivered at least one (1) year prior to the date of intended termination.
       
2)
QUANTITIES:
 
       
 
Maximum Daily Quantity (MDQ):  664,738 Dth/Day
       
3)
RECEIPT AND DELIVERY POINTS:
       
 
See Exhibit A
 
       
4)
RATE:
 
 
Service hereunder shall be provided pursuant to Rate Schedule FTS.  Customer shall pay, or cause to be paid, to MRT each month for all services provided hereunder the maximum applicable rate and any other charges specified in MRT’s FERC Gas Tariff, Third Revised Volume No. 1, as on file and in effect from time to time (“Tariff”), for services rendered hereunder, unless otherwise agreed (either in writing or electronically via the Internet as required by MRT) by MRT and Customer in an Exhibit B, or other format provided for in the Tariff, in effect during the term of this Agreement, or in a capacity release award.
       
5)
ADDRESSES:
 

 
For Notices to Customer:
For Bills to Customer:
 
Laclede Gas Company
Laclede Gas Company
 
Attn:  Steven F. Mathews
Attn: Gas Accounting
 
720 Olive Street
720 Olive Street, 13 Floor
 
St. Louis, MO 63101
St. Louis, MO 63101
 
Telephone:  (314) 516-8585
Telephone:  (314) 516-8595
 
Facsimile:    (314) 421-1979
Facsimile:    (314) 241-2278
 
E-Mail:  smathews@lacledegas.com
 
     
 
For Notices to MRT:
For Payments to MRT:
 
1600 S. Brentwood Blvd., Suite 590
P.O. Box 203293
 
St. Louis, MO 63144
Houston, TX 77216-3293
 
Facsimile:  (314) 991-7600
Facsimile:  (318) 429-3133
   
(payment detail – Shreveport)


Page  1 of 5
 
 
 
 
Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY




 
MRT Nominations (other than electronic):
 
 
Client Services
For Wire Transfer Payment to MRT:
 
Facsimile:  (318) 429-3298
Mississippi River Transmission
   
Chase Bank of Texas
 
MRT Pipeline Operations:
ABA No. 113000609
 
System Control Department
Account No.
 
1600 S. Brentwood Blvd., Suite 590
 
 
St. Louis, MO 63144
 
 
Telephone: (314) 991-9900
 
 
E-Mail:  mrtconsole@centerpointenergy.com
 

 
IN WITNESS WHEREOF, the parties have executed this Agreement as of the last date shown below.


CENTERPOINT ENERGY - MISSISSIPPI RIVER
LACLEDE GAS COMPANY
 
TRANSMISSION CORPORATION
       
           
           
By:
/s/ Robert Trost
 
By:
/s/ Kenneth J. Neises
 
Name
Robert Trost
 
Name:
Kenneth J. Neises
 
Title
Division Vice President – Marketing MRT
 
Title:
Executive Vice President
 
Date:
March 18, 2008
 
Date:
March 18, 2008
 
           





Page 2 of 5
 
 
 
 
Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY


GENERAL TERMS AND CONDITIONS

1)
Upon termination hereof for whatever reason, Customer agrees to stop delivering gas to MRT for transportation hereunder.  In addition, upon termination of this Agreement, Customer agrees that it will thereafter make no further demand for service hereunder and MRT agrees that it will make no further demand for the continuation of services or any payment related thereto, other than payments which are due with respect to any services previously provided.  Customer agrees to cooperate with and assist MRT in obtaining whatever regulatory approvals and authorizations, if any, are necessary or appropriate in view of such termination and abandonment of service hereunder.
   
2)
Termination of this Agreement shall not relieve either party of any obligation that might otherwise exist to correct any volume imbalance hereunder nor relieve Customer of its obligation to pay any monies due hereunder to MRT.
   
3)
In accordance with the terms and conditions of Section 17 of the General Terms and Conditions of MRT’s FERC Gas Tariff, Third Revised Volume No. 1 (General Terms and Conditions), if Customer fails to pay within thirty (30) days after payment is due all of the amount of any bill for service rendered by MRT hereunder, MRT, upon ten (10) days’ prior written notice to Customer, may suspend further receipt and/or delivery of gas until such past due amount is paid, or satisfactory credit arrangements have been made in accordance with Section 5 of the General Terms and Conditions.  If Customer fails to pay or make satisfactory credit arrangements within such ten (10) day notice period, MRT, in addition to any other remedy it may have hereunder, may, upon thirty (30) days’ written notice to Customer, terminate this Agreement and cease further receipt and/or delivery of gas on behalf of Customer.
   
4)
Service hereunder shall be provided pursuant to Rate Schedule FTS of MRT’s FERC Gas Tariff, Third Revised Volume No. 1.  Customer will provide Fuel Use and LUFG.
   
5)
This Agreement shall be subject to the provisions of the applicable rate schedule as well as the General Terms and Conditions set forth in MRT’s FERC Gas Tariff, Third Revised Volume No. 1, as on file and in effect from time to time, and such provisions are incorporated herein by this reference.  Any curtailment of transportation service hereunder shall be in accordance with the priorities set out in MRT’s General Terms and Conditions.  To the extent not inconsistent with effective law, MRT shall have the right to determine the priority and/or scheduling of the transportation service under this Agreement and to revise the priority and/or scheduling of this transportation service from time to time.
   
6)
MRT shall have the right at any time and from time to time to file and place into effect unilateral changes or modifications in the rates and charges, and other terms and conditions of service hereunder, as set forth in the applicable rate schedule and in the General Terms and Conditions, in accordance with the Natural Gas Act or other applicable law.
   
7)
Customer may deliver or cause to be delivered to MRT a maximum receipt point quantity at the Receipt Points described herein, and MRT shall redeliver thermally equivalent  quantities  at  the  Delivery  Points described herein which excludes a quantity of gas for Fuel Use and LUFG.  A maximum delivery point quantity is also specified for each MRT delivery point.  For firm service, the sum of all individual maximum receipt point quantities shall not exceed the maximum receipt point quantities in the aggregate.  For firm service, the sum of all individual maximum delivery point quantities shall not exceed the maximum daily quantity set forth in this Agreement.
   
8)
For firm service, Secondary Receipt and Secondary Delivery Points are available to Customer pursuant to the General Terms and Conditions of MRT’s FERC Gas Tariff, Third Revised Volume No. 1.  Customer agrees to pay any additional charges applicable to its utilization of a Secondary Receipt Point.
   
9)
In the event that MRT places on file with the Commission another rate schedule which may be applicable to service rendered hereunder, then MRT, at its option, may, from and after the effective date of such rate schedule, utilize such rate schedule in the performance of this Agreement.  Such rate schedule or superseding rate schedule(s) and any revisions thereof which shall be filed and become effective shall apply to and be a part of this Agreement.  MRT shall have the right to propose, file and make effective with the Commission, or other body having jurisdiction, changes and revisions of any effective rate schedule(s) and/or General Terms and Conditions, or to propose, file, and make effective superseding rate schedules and/or General Terms and Conditions, for the purpose of changing the rates, charges, and other provisions thereof effective as to Customer.


Page 3 of 5
 
 
 
 
Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

GENERAL TERMS AND CONDITIONS
(continued)


10)
Except as provided in this paragraph, this Agreement shall not be assigned by Customer in whole or in part without MRT’s prior written or electronic consent, which consent shall not be unreasonably withheld.  Customers under Rate Schedules FTS and SCT may release their capacity consistent with the terms and conditions of the applicable rate schedule and the General Terms and Conditions of MRT’s Tariff.  Additionally, Customer may request that MRT consent to Customer’s assignment of this Agreement, in whole, to an entity affiliated with Customer.  For firm contracts, MRT will only consent to assignment of the contract to a Customer’s affiliate, subject to the assignee’s satisfaction of the criteria in Section 5.4(k), General Terms and Conditions, in the situation in which, after Customer obtains the contract, a corporate reorganization results in a transfer to an affiliate of the function for which the capacity was obtained.  Any entity that succeeds by purchase, merger, consolidation or otherwise to the properties of Customer, substantially as an entirety, shall be entitled to the rights and shall be subject to the obligations of its predecessors in title under this Agreement.  In addition to all other rights and remedies, MRT may terminate the Agreement immediately if it is assigned by Customer without MRT’s consent, whether the assignment or contract be voluntary or by operation of law or otherwise.  Subject to the above, the respective rights and obligations of the parties under the Agreement shall extend to and be binding upon their heirs, successors, assigns and legal representatives.
   
11)
Any notice, statement, or bill provided for in this Agreement shall be in writing (or, if this tariff requires, via electronic means) and shall be considered as fully delivered when hand-delivered, telecopied, or when received by the other party if mailed by United States mail, postage prepaid, to the addresses specified herein (unless and until either party notifies the other, in writing, of a change in its address).
   
12)
Each party shall notify the other in writing of the name, address, telephone number, telecopy number and e-mail address of the person or persons who shall have authority to act for such party in connection with this Agreement, and operating notices shall thereafter be served upon such person or persons.
   
13)
This Agreement constitutes the entire agreement between the parties and no waiver, representation or agreement, oral or otherwise, shall affect the subject matter hereof unless and until such waiver, representation or agreement is reduced to writing or, if MRT permits or requires, otherwise memorialized via electronic means, and executed by authorized representatives of the parties.  No waiver by either Customer or MRT of any one or more defaults by the other in performance of any of the provisions of the Agreement shall operate or be construed as a waiver of any other existing or future default or defaults, whether of a like or of a different character.
   
14)
THE INTERPRETATION AND PERFORMANCE OF THIS  AGREEMENT SHALL BE IN ACCORDANCE WITH THE LAWS OF THE STATE OF MISSOURI, EXCLUDING CONFLICTS OF LAW PRINCIPLES THAT WOULD REQUIRE THE APPLICATION OF THE LAWS OF A DIFFERENT JURISDICTION.
   
15)
Exhibits A and B attached hereto are incorporated into this Agreement in their entirety.
   
16)
This Agreement amends and restates the currently effective Service Agreement between the parties.
   
17)
The parties agree that Customer has the Right of First Refusal (ROFR).  If Customer chooses to exercise its ROFR, it shall do so by following the procedures applicable to the exercise of a ROFR provided for in the Tariff.
   
18)
Pursuant to Section 5.1(a), Rate Schedule NNT, of MRT’s Tariff, if after April 1, 2008 a firm customer of Customer (“Bypassing Customer”) directly connects with MRT and terminates its customer relationship with Customer, Customer shall have the right to reduce its MDQ, with corresponding reductions in other applicable MRT contract entitlements, upon written notice to MRT.  The parties intend that the amount of the reduction is to reflect the amount of capacity that Customer had reserved under this Agreement to serve on a firm basis those requirements of the Bypassing Customer that were being served on Customer’s system on April 1, 2008, whether or not those requirements as of April 1, 2008, were those of the Bypassing Customer or of a predecessor customer of Customer.  The amount of the MDQ reduction may be determined in one of two ways.  Customer may provide an affidavit to MRT setting out the Bypassing Customer’s contract demand on Customer for the contract year in which the bypass is to take place and the average of that contract demand and the Bypassing Customer’s contract demands on Customer for the two preceding contract years.  If Customer provides such an affidavit, the amount of the MDQ reduction shall equal the amount designated by Customer up to the greater of (1) the Bypassing Customer’s average
Page 4 of 5
 
 
 
 


Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY
 
GENERAL TERMS AND CONDITIONS
(continued)
 
   
 
contract demand amount set out in Customer’s affidavit or (2) the Bypassing Customer’s contract demand on Customer for the contract year in which the bypass is to take place.  Alternatively, if Customer proposes an MDQ reduction greater than the maximum amount described in the preceding sentence Customer shall provide MRT with the proposed amount of the MDQ reduction and the basis for that amount.  MRT’s agreement to the amount of the MDQ reduction proposed by Customer under this alternative shall not be withheld unreasonably.  This right to reduce MDQ can be exercised up to thirty (30) days after service commences to the Bypassing Customer over its direct connection with MRT as follows: the MDQ reduction will be effective the latest of (1) the first day of the second calendar month (a) after such service commences or (b) after exercise by Customer of its right or (2) the first day of the month after the termination of the Bypassing Customer’s customer relationship with Customer.  Nothing contained in paragraph 18 shall preclude Customer from claiming and exercising any additional rights to reduce MDQ available to bypassed LDCs under the policies promulgated by the FERC (see. e.g., Williams Natural Gas Company, 81 FERC ¶61,301 (1997) at 62,412), as modified or amended from time to time.
   
19)
Pursuant to Section 5.1(b), Rate Schedule NNT, of MRT’s Tariff, if Customer unbundles its combined sales and distribution services for its local distribution system pursuant to an order of any governing authority having jurisdiction (“Unbundling”), Customer and MRT shall cooperate through reasonable means in an effort to implement the Unbundling in a manner that is fair to both parties.  Among other opportunities for cooperation that may arise at the time to effectuate the ordered Unbundling in a reasonable manner, Customer and MRT will work together to assign to the appropriate entities, using the tariff capacity release procedures (or such other mechanisms as may be available at the time), capacity held by Customer under this Agreement to serve the customers whose services are being unbundled.  Revenues received by MRT from replacement shippers attributable to demand or reservation charge payments for such released capacity shall be credited to Customer, in accordance with the Tariff, to the extent of the demand or reservation charge obligation that Customer may have with respect to such capacity. With respect to the MRT capacity retained by Customer, if any, after the parties have cooperated to implement Unbundling as set out above, Customer will continue to have those rights relating to bypass set out in the preceding paragraph.
   
20)
In response to MRT’s News posting dated February 13, 2008, regarding proposed new Receipt Point interconnections to be established on MRT’s system, Customer requested a change in its existing Receipt Points as part of its agreement to extend this Agreement for five (5) years.  MRT agrees to allow this Receipt Point change subject to the following terms and conditions.  Effective with the in-service date of new MRT Receipt Point interconnections with Chesapeake Energy #1 and Chesapeake Energy #2 on MRT’s Transark Line, Customer’s Maximum Quantity at its CEGT Vilonia and Ozark Receipt Points shall be reduced by 30,500 Dth/day and 19,500 Dth/day, respectively, and a Maximum Quantity of 25,000 Dth/day at each of the new Chesapeake Energy #1 and Chesapeake Energy #2 Receipt Points shall be provided for on Exhibit A.  In the event the in-service date of the Chesapeake Energy #1 and Chesapeake Energy #2 Receipt Points are not contemporaneous, Customer’s Maximum Quantity at CEGT Vilonia shall be reduced first by 25,000 Dth/day, and a Maximum Quantity of 25,000 Dth/day shall be established at the first of the Chesapeake Energy #1 or Chesapeake Energy #2 Receipt Points to be placed in-service. On the in-service date of the second Chesapeake Receipt Point, Customer’s Maximum Quantity at its Ozark Receipt Point shall be reduced by 19,500 Dth/day, its CEGT Vilonia Receipt Point Maximum Quantity shall be reduced by an additional 5,500 Dth/day, and a Maximum Quantity of 25,000 Dth/day shall be provided for at such Chesapeake point.  Customer agrees to provide MRT written notice six (6) months after the effective date of this Agreement, and every six (6) months thereafter, of its continuing interest in reserving capacity at the Chesapeake Receipt Points.  This provision is subject to the establishment and placement in-service of the Chesapeake Receipt Points described above, and to Customer’s prompt execution of superseding Exhibit(s) A to this Agreement.


Page 5 of 5
 
 
 
 


Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

 
           
Page 1 of 2
EXHIBIT A
 
               
Primary Path(s):
             
 
From
     
To
   
 
#90571 Delhi @ Harrison
 
#91030 MOGAS Pipeline
   
 
#12817 Trunkline Gas Company
 
#805607  Storage
   
               
Rate Zone Capacity:
             
 
FLD
472,240
  Dth/Day
       
 
MKT
664,738
  Dth/Day
       
               
Line Capacities:
             
 
M
472,240
  Dth/Day
       
 
W
75,968
  Dth/Day
       
 
On any given day the Customer is entitled to the greater of
   
 
75,968 or 74.47% of available West Line capacity.
   
 
E
192,498
  Dth/Day
       
               
Line Priority:
             
 
FLD/M
396,272
  Dth/Day
       
 
MKT/M
472,240
  Dth/Day
       
 
FLD/W
75,968
  Dth/Day
       
 
MKT/E
192,498
  Dth/Day
       
               
Transportation Zones:
FLD:  Field Zone                                           MKT:  Market Zone
   
Service Lines:
E:  East Line   M:  Main Line   W:  West Line   O:  Off  System
   

RECEIPT AND DELIVERY POINTS
       
Receipt Points
Maximum Quantity (Dth/Day)*
Delivery Points
Maximum Quantity (Dth/Day)*
       
Delhi @ Harrison
35,000
Laclede Gas Aggregate
641,327
Meter # 90571
 
Meter #805526
 
       
Carthage
20,987
Missouri Interstate Gas
23,411
Meter #808526
 
Meter #91030
 
       
Waskom
18,540
Storage
664,738
Meter #808527
 
Meter #805607
 
       
Sligo
1,441
   
Meter #90386
     




 
 
 
 


Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY



Page 2 of 2

EXHIBIT A
(continued)

Gulf South Perryville
135,000
Meter #90496
 
   
Antioch Gas to MRT Transark
18,500
Meter #91120
 
   
Ozark
21,800
Meter #90523
 
   
CEGT Glendale
183,972
Meter #805547
 
   
CEGT Vilonia to MRT Transark
37,000
Meter #805614
 
   
Trunkline Gas Company
120,928
Meter #12817
 
   
NGPL @ Shattuc/Clinton
71,570
Meter # 805588
 
   
Storage
664,738
Meter #805607
 

*  On any day MRT shall not be obligated to receive or deliver a cumulative quantity in excess of the MDQ set forth in this Agreement.


CENTERPOINT ENERGY - MISSISSIPPI RIVER
LACLEDE GAS COMPANY
 
TRANSMISSION CORPORATION
       
           
           
By:
/s/ Robert Trost
 
By:
/s/ Kenneth J. Neises
 
Name
Robert Trost
 
Name:
Kenneth J. Neises
 
Title
Division Vice President – Marketing MRT
 
Title:
Executive Vice President
 
Date:
March 18, 2008
 
Date:
March 18, 2008
 
           


 
 
 
 


Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

Page 1 of 2
EXHIBIT B

Customer agrees to pay the rates specified on this Exhibit B for performance of certain gas transportation service under the Agreement specified above.  These rates are applicable only in accordance with the following:

RATES AND APPLICABILITY:

(a)
General:  In consideration for Customer's continuing compliance with the provisions of the Transportation Service Agreement ("Agreement") specified above, the transportation rates and charges as defined below for the specified services provided under the Agreement only apply to receipts from, and subsequent deliveries to, the Points of Receipt and Delivery, quantities and/or time periods described herein and to reserved capacity necessary to effect such service.  In addition to any rate or amount referred to herein (including discounted rates, Negotiated Rates, overrun rates and maximum tariff rates), Customer shall pay any applicable charges, penalties, surcharges, fees, taxes, settlements and/or direct billed amounts provided for in MRT's Tariff.  In any event, the rate in any month shall never be below MRT's applicable minimum tariff rate for a discount rate transaction.  For a Negotiated Rate transaction, the rate in any month shall never be below MRT's applicable minimum tariff rate, unless MRT otherwise agrees.  MRT shall not be responsible for the payment and satisfaction of any taxes assessed or levied on the receipt, transmission (and any activities in connection therewith), delivery, use and/or consumption with respect to gas delivered or received by Customer, unless MRT agrees otherwise.

(b)
Inability to Collect Negotiated Rates:  If this Exhibit B covers a Negotiated Rate transaction, and MRT is unable to collect Negotiated Rates due to a change in Commission policy or rejection of the transaction by the Commission prior to or during the term of such transaction, then, unless the parties agree otherwise, Customer shall pay the maximum tariff rate for the services.  In such event, MRT shall notify Customer in writing of the requirement to pay maximum tariff rates and, if the maximum tariff rates are greater than the Negotiated Rates under such transaction, Customer shall have no more than thirty (30) days from the date of such notification to give notice in writing of termination of the applicable Agreement, with such termination to be effective no later than the end of the month following the month in which such termination notice is received.

(c)
Points:  The Receipt Point(s) and the Delivery Point(s) eligible for the rates specified herein shall be as set forth in Exhibit A.
   
(d) Description of Rate:                              Negotiated Rate     [    ]                           Discounted Rate     [ X ]      (Check one)
 
 
(i)
Base Rate:  Customer’s rate for service shall be the maximum Base Rate(s) for Rate Schedule FTS, as set forth in MRT’s Tariff from time to time; provided, however, that during the term of this Agreement, the Base Rate(s) paid by Customer shall not exceed the maximum Base Rate Reservation and Usage Charges set forth on Sixty-Second Revised Sheet No. 5 (effective November 1, 2007), or if as a result of a rate design change in a Section 4 or 5 rate proceeding, the equivalent of the maximum Base Rate Reservation and Usage Charge(s) set forth on Sixty-Second Revised Sheet No. 5 when computed at an assumed 100% Load Factor, as follows:
                                                                        
 Field to Market Zone Transportation:   $0.1432 per Dth
 Field Zone Only Transportation:     $0.0736 per Dth
 Market Zone Only Transportation:  $0.0696 per Dth
                                                                                                         
 
(ii)
Surcharges: All applicable Rate Schedule FTS surcharges, penalties, charges, fees, taxes, settlements, direct billed amounts, and Fuel Use and LUFG retentions provided in MRT’s Tariff.
                             
 (e)          Term of Rate:   Begin Date (s): April 1, 2008
 
End Date(s):
Primary Term End Date and continuing thereafter unless and until terminated by either MRT or Customer by written notice or electronically via the Internet as permitted or required by MRT, to the other delivered at least one (1) year prior to the date of the intended termination.

(f)
Authorized Overrun:  For discounted rate transactions, any authorized overrun quantities shall be at the assumed 100% load factor derivative of the Base Rate(s) set forth in (d) above, plus all applicable Rate Schedule FTS surcharges, penalties, and Fuel Use and LUFG retentions.

 
 
 
 


Contract No. 3310
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY


Page 2 of 2
EXHIBIT B
(continued)

 (g)
Rate-Related Provisions:

 
(i)
Consideration for Rate Granted:  MRT agrees to the rates specified in this Exhibit B in exchange for Customer's agreement to forego credits or other benefits to which Customer would otherwise be entitled under the Agreement, but only to the extent such credits or benefits would result in a greater economic benefit over the term of this Exhibit B than that represented by the agreed-upon rate.  Accordingly, unless MRT otherwise agrees, Customer will not receive credits (with the exception of (1) penalty revenue credits provided pursuant to Section 34 of the General Terms and Conditions of MRT's Tariff, and (2) capacity release credits) from rates, refunds or other revenues collected by MRT or Customer if to do so would effectively result in a lower rate or greater economic benefit to Customer; provided, however, that (I) for a Customer taking service under a discount or recourse rate agreement, the rate in any month shall never be above MRT's applicable maximum tariff rate, and (II) MRT and a Customer taking service under a Negotiated Rate agreement can agree pursuant to Section 14.2 of the General Terms and Conditions of MRT's Tariff that MRT will retain some or all of the capacity release credits to the extent those credits exceed the amount of the Customer's invoiced demand component.  If the parties' agreement to the foregoing is determined invalid or if Customer seeks to obtain credits or benefits inconsistent therewith, unless MRT otherwise agrees, it will have the right to immediately terminate or modify any provisions of this Exhibit B that would allow Customer to pay amounts less than the maximum applicable tariff rate.

 
(ii)
Regulatory Authority:  This Exhibit B is subject to Section 30 of the General Terms and Conditions of MRT's Tariff.  MRT and Customer hereby acknowledge that this Exhibit B is subject to all valid and applicable federal and local laws and to the orders, rules and regulations of any constituted federal or local regulatory body or governmental authority having jurisdiction.  Any provision of this Exhibit B which is determined by any court or regulatory body having jurisdiction to be invalid or unenforceable will be ineffective to the extent of such determination only, without invalidating, or otherwise affecting the validity of, the remaining provisions.  Except as otherwise provided in subsection (b) above, unless the parties agree otherwise, if MRT  reasonably determines that a federal or local law, or order, rule or regulation of any governmental authority having or asserting jurisdiction (1) requires performance by MRT that is inconsistent with the terms of this Exhibit B, or (2) conditions or prohibits the granting of selective discounts or other rates specified in paragraph (d) of this Exhibit B, then MRT and Customer shall promptly take all reasonable actions in good faith to enter into alternative arrangements that will secure to the maximum extent practicable for each party all of the benefits of the transaction set out in this Agreement; provided however, that MRT shall not be required to enter into or continue arrangements that would result in a greater economic detriment to MRT than existed prior to the regulatory event or change.

Executed by a duly authorized representative of each party hereto, in the space provided below:

CENTERPOINT ENERGY - MISSISSIPPI RIVER
LACLEDE GAS COMPANY
 
TRANSMISSION CORPORATION
       
           
           
By:
/s/ Robert Trost
 
By:
/s/ Kenneth J. Neises
 
Name
Robert Trost
 
Name:
Kenneth J. Neises
 
Title
Division Vice President – Marketing MRT
 
Title:
Executive Vice President
 
Date:
March 18, 2008
 
Date:
March 18, 2008
 
           


 
 
 
 

EX-10.7 8 ex10-7.htm EXHIBIT 10.7 ex10-7.htm

Exhibit 10.7
Contract  #3311
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

This TRANSPORTATION SERVICE AGREEMENT, hereinafter referred to as "Agreement," is made and entered into on this by and between CenterPoint Energy - Mississippi River Transmission Corporation, a Delaware corporation, hereinafter called "MRT," and Laclede Gas Co., a Missouri corporation, hereinafter called "Customer."

In consideration of the mutual covenants herein contained, the parties hereto agree that MRT shall transport for Customer, on a firm basis, and Customer shall furnish, or cause to be furnished, to MRT natural gas for such transportation during the term hereof, at the rates and on the terms and conditions hereinafter provided.

1)
TERM
       
 
Effective Date:
Originally May 1, 2002, as amended and restated effective April 1, 2008
 
Primary Term End Date:
April 30, 2013
       
 
Evergreen?
Yes  [ X ]          No  [    ]  
     
    After the Primary Term End Date, this Agreement shall continue to be in effect thereafter unless and until terminated by either MRT or Customer by written notice or electronically via the Internet as permitted or required by MRT, to the other delivered at least one (1) year prior to the date of intended termination.   
       
2)
QUANTITIES
 
       
 
Maximum Daily Quantity (MDQ):  150,000 Dth/Day
       
3)
RECEIPT AND DELIVERY POINTS
       
 
See Exhibit A
 
       
4)
RATE
 
     
 
Service hereunder shall be provided pursuant to Rate Schedule FTS.  Customer shall pay, or cause to be paid, to MRT each month for all services provided hereunder the maximum applicable rate and any other charges specified in MRT's FERC Gas Tariff, Third Revised Volume No. 1, as on file and in effect from time to time (“Tariff”), for services rendered hereunder, unless otherwise agreed (either in writing or electronically via the Internet as required by MRT) by MRT and Customer in an Exhibit B, or other format provided for in the Tariff, in effect during the term of this Agreement, or in a capacity release award.
       
5)
ADDRESSES
 

 
For Notices to Customer:
For Bills to Customer:
 
Laclede Gas Company
Laclede Gas Company
 
Attn:  Steven F. Mathews
Attn: Gas Accounting
 
720 Olive Street
720 Olive Street, 13th  Floor
 
St. Louis, MO 63101
St. Louis, MO 63101
 
Telephone:  (314) 516-8585
Telephone:  (314) 516-8595
 
Facsimile:    (314) 421-1979
Facsimile:    (314) 241-2278
 
E-Mail:  smathews@lacledegas.com
 
     
 
For Notices to MRT:
For Payments to MRT:
 
1600 S. Brentwood Blvd., Suite 590
P.O. Box 203293
 
St. Louis, MO 63144
Houston, TX 77216-3293
 
Facsimile:  (314) 991-7600
 
     


Page 1 of 4
 
 
 
 
Contract #3311
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY




   
For Wire Transfer Payment to MRT:
 
MRT Nominations (other than electronic):
Mississippi River Transmission
 
Client Services
Chase Bank of Texas
 
Facsimile:  (318) 429-3298
ABA No. 113000609
   
Account No.
 
MRT Pipeline Operations:
 
 
System Control Department
 
 
1600 S. Brentwood Blvd., Suite 590
 
 
St. Louis, MO 63144
 
 
Telephone: (314) 991-9900
 
 
E-Mail:  mrtconsole@centerpointenergy.com
 
     

IN WITNESS WHEREOF, the parties have executed this Agreement as of the last date shown below.


CENTERPOINT ENERGY - MISSISSIPPI RIVER
LACLEDE GAS COMPANY
 
TRANSMISSION CORPORATION
       
           
           
By:
/s/ Robert Trost
 
By:
/s/ Kenneth J. Neises
 
Name
Robert Trost
 
Name:
Kenneth J. Neises
 
Title
Division Vice President – Marketing MRT
 
Title:
Executive Vice President
 
           
Date:
March 18, 2008
 
Date:
March 18, 2008
 
           





  Page 2 of 4
 
 
 
Contract #3311
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY


GENERAL TERMS AND CONDITIONS

1)
Upon termination hereof for whatever reason, Customer agrees to stop delivering gas to MRT for transportation hereunder.  In addition, upon termination of this Agreement, Customer agrees that it will thereafter make no further demand for service hereunder and MRT agrees that it will make no further demand for the continuation of services or any payment related thereto, other than payments which are due with respect to any services previously provided.  Customer agrees to cooperate with and assist MRT in obtaining whatever regulatory approvals and authorizations, if any, are necessary or appropriate in view of such termination and abandonment of service hereunder.
   
2)
Termination of this Agreement shall not relieve either party of any obligation that might otherwise exist to correct any volume imbalance hereunder nor relieve Customer of its obligation to pay any monies due hereunder to MRT.
   
3)
In accordance with the terms and conditions of Section 17 of the General Terms and Conditions of MRT's FERC Gas Tariff, Third Revised Volume No. 1 (General Terms and Conditions), if Customer fails to pay within thirty (30) days after payment is due all of the amount of any bill for service rendered by MRT hereunder, MRT, upon ten (10) days' prior written notice to Customer, may suspend further receipt and/or delivery of gas until such past due amount is paid, or satisfactory credit arrangements have been made in accordance with Section 5 of the General Terms and Conditions.  If Customer fails to pay or make satisfactory credit arrangements within such ten (10) day notice period, MRT, in addition to any other remedy it may have hereunder, may, upon thirty (30) days' written notice to Customer, terminate this Agreement and cease further receipt and/or delivery of gas on behalf of Customer.
   
4)
Service hereunder shall be provided pursuant to Rate Schedule FTS of MRT's FERC Gas Tariff, Third Revised Volume No. 1.  Customer will provide Fuel Use and LUFG.
   
5)
This Agreement shall be subject to the provisions of the applicable rate schedule as well as the General Terms and Conditions set forth in MRT's FERC Gas Tariff, Third Revised Volume No. 1, as on file and in effect from time to time, and such provisions are incorporated herein by this reference.  Any curtailment of transportation service hereunder shall be in accordance with the priorities set out in MRT's General Terms and Conditions.  To the extent not inconsistent with effective law, MRT shall have the right to determine the priority and/or scheduling of the transportation service under this Agreement and to revise the priority and/or scheduling of this transportation service from time to time.
   
6)
MRT shall have the right at any time and from time to time to file and place into effect unilateral changes or modifications in the rates and charges, and other terms and conditions of service hereunder, as set forth in the applicable rate schedule and in the General Terms and Conditions, in accordance with the Natural Gas Act or other applicable law.
   
7)
Customer may deliver or cause to be delivered to MRT a maximum receipt point quantity at the Receipt Points described herein, and MRT shall redeliver thermally equivalent quantities at the Delivery Points described herein which excludes a quantity of gas for Fuel Use and LUFG.  A maximum delivery point quantity is also specified for each MRT delivery point.  For firm service, the sum of all individual maximum receipt point quantities shall not exceed the maximum receipt point quantities in the aggregate.  For firm service, the sum of all individual maximum delivery point quantities shall not exceed the maximum daily quantity set forth in this Agreement.
   
8)
For firm service, Secondary Receipt and Secondary Delivery Points are available to Customer pursuant to the General Terms and Conditions of MRT's FERC Gas Tariff, Third Revised Volume No. 1.  Customer agrees to pay any additional charges applicable to its utilization of a Secondary Receipt Point.
   
9)
In the event that MRT places on file with the Commission another rate schedule which may be applicable to service rendered hereunder, then MRT, at its option, may, from and after the effective date of such rate schedule, utilize such rate schedule in the performance of this Agreement.  Such rate schedule or superseding rate schedule(s) and any revisions thereof which shall be filed and become effective shall apply to and be a part of this Agreement.  MRT shall have the right to propose, file and make effective with the Commission, or other body having jurisdiction, changes and revisions of any effective rate schedule(s) and/or General Terms and Conditions, or to propose, file, and make effective superseding rate schedules and/or General Terms and Conditions, for the purpose of changing the rates, charges, and other provisions thereof effective as to Customer.


  Page 3 of 4
 
 
 
Contract #3311
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

GENERAL TERMS AND CONDITIONS
(continued)


10)
Except as provided in this paragraph, this Agreement shall not be assigned by Customer in whole or in part without MRT's prior written or electronic consent, which consent shall not be unreasonably withheld.  Customers under Rate Schedules FTS and SCT may release their capacity consistent with the terms and conditions of the applicable rate schedule and the General Terms and Conditions of MRT's Tariff.  Additionally, Customer may request that MRT consent to Customer’s assignment of this Agreement, in whole, to an entity affiliated with Customer.  For firm contracts, MRT will only consent to assignment of the contract to a Customer’s affiliate, subject to the assignee’s satisfaction of the criteria in Section 5.4(k), GT&C, in the situation in which, after Customer obtains the contract, a corporate reorganization results in a transfer to an affiliate of the function for which the capacity was obtained.  Any entity that succeeds by purchase, merger, consolidation or otherwise to the properties of Customer, substantially as an entirety, shall be entitled to the rights and shall be subject to the obligations of its predecessors in title under this Agreement.  In addition to all other rights and remedies, MRT may terminate the Agreement immediately if it is assigned by Customer without MRT's consent, whether the assignment or contract be voluntary or by operation of law or otherwise.  Subject to the above, the respective rights and obligations of the parties under the Agreement shall extend to and be binding upon their heirs, successors, assigns and legal representatives.
   
11)
Any notice, statement, or bill provided for in this Agreement shall be in writing (or, if this Tariff requires, via electronic means) and shall be considered as fully delivered when hand-delivered, telecopied, or when received by the other party if mailed by United States mail, postage prepaid, to the addresses specified herein (unless and until either party notifies the other, in writing, of a change in its address).
   
12)
Each party shall notify the other in writing of the name, address, telephone number,  telecopy number and e-mail address of the person or persons who shall have authority to act for such party in connection with this Agreement, and operating notices shall thereafter be served upon such person or persons.
   
13)
This Agreement constitutes the entire agreement between the parties and no waiver, representation or agreement, oral or otherwise, shall affect the subject matter hereof unless and until such waiver, representation or agreement is reduced to writing or, if MRT permits or requires, otherwise memorialized via electronic means, and executed by authorized representatives of the parties.  No waiver by either Customer or MRT of any one or more defaults by the other in performance of any of the provisions of the Agreement shall operate or be construed as a waiver of any other existing or future default or defaults, whether of a like or of a different character.
   
14)
THE INTERPRETATION AND PERFORMANCE OF THIS AGREEMENT SHALL BE IN ACCORDANCE WITH THE LAWS OF THE STATE OF MISSOURI, EXCLUDING CONFLICTS OF LAW PRINCIPLES THAT WOULD REQUIRE THE APPLICATION OF THE LAWS OF A DIFFERENT JURISDICTION.
   
15)
Exhibit(s) A and B attached hereto are incorporated into this Agreement in their entirety.
   
16)
This Agreement amends and restates the currently effective Service Agreement between the parties.
   
17)
The parties agree that Customer has the Right of First Refusal (ROFR).  If customer chooses to exercise its ROFR, it shall do so by following the procedures applicable to the exercise of a ROFR provided for in the Tariff.



  Page 4 of 4
 
 
 


Contract #3311
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY


           
Page 1 of 1
EXHIBIT A
 
               
Primary Path(s)
             
 
From
     
To
   
 
#805547 CEGT-Glendale
 
#805596 CEGT-Perryville
   
     
#805607 MRT Storage
   
               
 
#805602 CEGT-Olyphant
 
#805596 CEGT-Perryville
   
         
#805607 MRT Storage
   
               
Line Capacity
150,000 Dth/Day Main Line Field Zone
     
Line Priority
150,000 Dth/Day Field Zone Main Line
     
               
Rate Zone Capacity
 
150,000 Dth/Day Field Zone
     

RECEIPT AND DELIVERY POINTS
           
Receipt Point
 
Maximum Quantity *
Delivery Point(s)
 
Maximum Quantity *
805547
 
100,000 Dth/Day
*STG
 
150,000 Dth/Day
 
CenterPoint Energy Gas Transmission
Company (“CEGT”)/Glendale Interconnect;
SW/4, Section 5, T9N, R8W;
Meter #80547
 
 
MRT Storage
MRT’s storage facilities primarily located in Lincoln Parish, LA;
Meter #805607
805602
50,000 Dth/Day
805596
 
150,000 Dth/Day
 
CEGT/Olyphant Interconnect;
Section 7, T10N, R3W;
Meter #805602
 
CEGT/Perryville Interconnect
(Located on MRT Main Line system);
NE/4, Section 24, T20N, R4W
Meter #805596

* On any day MRT shall not be obligated to receive or deliver a cumulative quantity in excess of the MDQ set forth in this Agreement.


CENTERPOINT ENERGY - MISSISSIPPI RIVER
LACLEDE GAS COMPANY
 
TRANSMISSION CORPORATION
       
           
           
By:
/s/ Robert Trost
 
By:
/s/ Kenneth J. Neises
 
Name
Robert Trost
 
Name:
Kenneth J. Neises
 
Title
Division Vice President – Marketing MRT
 
Title:
Executive Vice President
 
           
Date:
March 18, 2008
 
Date:
March 18, 2008
 
           



 
 
 
 


Contract #3311
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY


Page 1 of 3
EXHIBIT B

Customer agrees to pay the rates specified on this Exhibit B for performance of certain gas transportation service under the Agreement specified above.  These rates are applicable only in accordance with the following:

RATES AND APPLICABILITY:

(a)
General:  In consideration for Customer's continuing compliance with the provisions of the Transportation Service Agreement ("Agreement") specified above, the transportation rates and charges as defined below for the specified services provided under the Agreement only apply to receipts from, and subsequent deliveries to, the Points of Receipt and Delivery, quantities and/or time periods described herein and to reserved capacity necessary to effect such service.  In addition to any rate or amount referred to herein (including discounted rates, Negotiated Rates, overrun rates and maximum tariff rates), Customer shall pay any applicable charges, penalties, surcharges, fees, taxes, settlements and/or direct billed amounts provided for in MRT's Tariff.  In any event, the rate in any month shall never be below MRT's applicable minimum tariff rate for a discount rate transaction.  For a Negotiated Rate transaction, the rate in any month shall never be below MRT's applicable minimum tariff rate, unless MRT otherwise agrees.  MRT shall not be responsible for the payment and satisfaction of any taxes assessed or levied on the receipt, transmission (and any activities in connection therewith), delivery, use and/or consumption with respect to gas delivered or received by Customer, unless MRT agrees otherwise.

(b)
Inability to Collect Negotiated Rates:  If this Exhibit B covers a Negotiated Rate transaction, and MRT is unable to collect Negotiated Rates due to a change in Commission policy or rejection of the transaction by the Commission prior to or during the term of such transaction, then, unless the parties agree otherwise, Customer shall pay the maximum tariff rate for the services.  In such event, MRT shall notify Customer in writing of the requirement to pay maximum tariff rates and, if the maximum tariff rates are greater than the Negotiated Rates under such transaction, Customer shall have no more than thirty (30) days from the date of such notification to give notice in writing of termination of the applicable Agreement, with such termination to be effective no later than the end of the month following the month in which such termination notice is received.

(c)
Points:  The Receipt Point(s) and the Delivery Point(s) eligible for the rates specified herein shall be as set forth in Exhibit A and (d)(iv) below.
   
(d) Description of Rate:                              Negotiated Rate [    ]                                       Discounted Rate [ X ] (Check one)          
 

 
(i)
Reservation Charge:
$0.8390/Dth
       
 
(ii)
Usage Charge:
$0.0015/Dth
 
 
(iii)
Any applicable Rate Schedule FTS surcharges, penalties, charges, fees, taxes, settlements, direct billed amounts, and Fuel Use and LUFG retentions provided for in MRT’s Tariff.

 
(iv)
In addition to the points specified above, the discounted rates set forth herein shall apply to deliveries to MRT’s interconnect with Gulf South at Perryville on a secondary basis.  Deliveries to Gulf South are operationally feasible only when MRT is receiving sufficient quantities of gas into its system from Gulf South to make deliveries for Customer by displacement.  The discounted rates shall also apply to receipts from the Secondary Receipt Points described below in this Section (d)(iv), provided that such receipts are subsequently delivered to the TETCO-White County Secondary Delivery Point (no more than 30,000 Dth/Day) and/or the MRT Storage Delivery Point described on Exhibit A, and further provided that the quantities received from each Secondary Receipt Point described below in this Section (d)(iv) do not exceed 50,000 Dth/Day from each such point.  Any other services under this FTS Agreement shall be at MRT’s maximum applicable FTS tariff rate.

 
 
 
 


Contract #3311
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

 
Page 2 of 3
 
 EXHIBIT B
 
(continued)
 
            Secondary Receipt Point(s):
            
            NGPP
Natural Gas Pipeline
Randolph County
Meter #90498
 
            OZRK
Ozark Gas Transmission
Meter #90523
            
            AGLE
CEGT-Glendale
Meter #805547
 
            Secondary Delivery Point(s):
 
            TEWC
Texas Eastern-White County
Meter #13316
 
            PRVL
Gulf South-Perryville
Meter #90496

 
 e)           Term of Rate: Begin Date(s): April 1, 2008
     
 
End Date(s):
Primary Term and continuing thereafter unless and until terminated by either MRT or Customer by written notice or electronically via the Internet as permitted or required by MRT, to the other delivered at least one (1) year prior to the date of the intended termination.
   
(f) Authorized Overrun:            For discounted rate transactions, any authorized overrun quantities shall be at the following rate:  $0.0292/Dth.
   
(g)
Rate-Related Provisions:
 
 
(i)
Consideration for Rate Granted:  MRT agrees to the rates specified in this Exhibit B in exchange for Customer's agreement to forego credits or other benefits to which Customer would otherwise be entitled under the Agreement, but only to the extent such credits or benefits would result in a greater economic benefit over the term of this Exhibit B than that represented by the agreed-upon rate.  Accordingly, unless MRT otherwise agrees, Customer will not receive credits (with the exception of (1) penalty revenue credits provided pursuant to Section 34 of the General Terms and Conditions of MRT's Tariff, and (2) capacity release credits) from rates, refunds or other revenues collected by MRT or Customer if to do so would effectively result in a lower rate or greater economic benefit to Customer; provided, however, that (I) for a Customer taking service under a discount or recourse rate agreement, the rate in any month shall never be above MRT's applicable maximum tariff rate, and (II) MRT and a Customer taking service under a Negotiated Rate agreement can agree pursuant to Section 14.2 of the General Terms and Conditions of MRT's Tariff that MRT will retain some or all of the capacity release credits to the extent those credits exceed the amount of the Customer's invoiced demand component.  If the parties' agreement to the foregoing is determined invalid or if Customer seeks to obtain credits or benefits inconsistent therewith, unless MRT otherwise agrees, it will have the right to immediately terminate or modify any provisions of this Exhibit B that would allow Customer to pay amounts less than the maximum applicable tariff rate.

 
 
 
 


Contract #3311
AMENDED AND RESTATED
TRANSPORTATION SERVICE AGREEMENT
FOR RATE SCHEDULE FTS
BETWEEN CENTERPOINT ENERGY - MISSISSIPPI RIVER TRANSMISSION CORPORATION
AND LACLEDE GAS COMPANY

 
Page 3 of 3

 
EXHIBIT B
 
(continued)

 
(ii)
Regulatory Authority:  This Exhibit B is subject to Section 30 of the General Terms and Conditions of MRT's Tariff.  MRT and Customer hereby acknowledge that this Exhibit B is subject to all valid and applicable federal and local laws and to the orders, rules and regulations of any constituted federal or local regulatory body or governmental authority having jurisdiction.  Any provision of this Exhibit B which is determined by any court or regulatory body having jurisdiction to be invalid or unenforceable will be ineffective to the extent of such determination only, without invalidating, or otherwise affecting the validity of, the remaining provisions.  Except as otherwise provided in subsection (b) above, unless the parties agree otherwise, if MRT  reasonably determines that a federal or local law, or order, rule or regulation of any governmental authority having or asserting jurisdiction (1) requires performance by MRT that is inconsistent with the terms of this Exhibit B, or (2) conditions or prohibits the granting of selective discounts or other rates specified in paragraph (d) of this Exhibit B, then MRT and Customer shall promptly take all reasonable actions in good faith to enter into alternative arrangements that will secure to the maximum extent practicable for each party all of the benefits of the transaction set out in this Agreement; provided however, that MRT shall not be required to enter into or continue arrangements that would result in a greater economic detriment to MRT than existed prior to the regulatory event or change.


Executed by a duly authorized representative of each party hereto, in the space provided below:


CENTERPOINT ENERGY - MISSISSIPPI RIVER
LACLEDE GAS COMPANY
 
TRANSMISSION CORPORATION
       
           
           
By:
/s/ Robert Trost
 
By:
/s/ Kenneth J. Neises
 
Name
Robert Trost
 
Name:
Kenneth J. Neises
 
Title
Division Vice President – Marketing MRT
 
Title:
Executive Vice President
 
           
Date:
March 18, 2008
 
Date:
March 18, 2008
 
           



 
 
 
 

EX-10.8 9 ex10-8.htm EXHIBIT 10.8 ex10-8.htm


Exhibit 10.8

FIRST AMENDMENT TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT

THIS FIRST AMENDMENT TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT (this “Amendment”) is made and entered into as of March 31, 2008, by and between THE LACLEDE GROUP, INC., a Missouri corporation (“Borrower”), and U.S. BANK NATIONAL ASSOCIATION, formerly known as Firstar Bank, N.A., a national banking association (“Lender”), and has reference to the following facts and circumstances (the “Recitals”):

A.           Borrower and Lender executed the Amended and Restated Revolving Credit Agreement dated as of August 4, 2005 (as amended, the “Agreement”; all capitalized terms used and not otherwise defined in this Amendment shall have the respective meanings ascribed to them in the Agreement as amended by this Amendment), pursuant to which Borrower executed the Revolving Credit Note dated August 4, 2005, payable to the order of Lender, in the principal amount of up to $40,000,000 (as amended, the “Note”).

B.           Borrower and Lender desire to amend the Agreement, in the manner hereinafter set forth.

NOW, THEREFORE, in consideration of the premises and for other good and valuable consideration, the receipt and sufficiency of which are hereby acknowledged, Borrower and Lender hereby agree as follows:

1.           Recitals.  The Recitals are true and correct, and, together with the defined terms set forth therein, are incorporated herein by this reference.

2.           Amendment to Agreement.  The Agreement is amended as follows:

(a)          The definition of “Guaranty” in Section 1.01 of the Agreement is deleted and substituted with the following:

Guaranty” or “Guaranties” shall mean the Guaranty dated as of August 4, 2005, executed by Laclede
  Energy in favor of Lender, as the same may from time to time be amended, modified, extended, renewed or
  restated.”

(b)          The definition of “SM&P” in Section 1.01 of the Agreement and all references to SM&P in the Agreement are deleted.

(c)          Section 4.07 of the Agreement is deleted and replaced with the following:
4.07 Investment Company Act of 1940; Public Utility Holding Company Act of 2005. Borrower
                           is not an “investment company” as that term is defined in, and is not otherwise subject to regulation
                           under, the Investment Company Act of 1940, as amended. Borrower is a holding company for which
                           compliance with the accounting, record retention and reporting sections of the Public Utility Holding
                           Company Act of 2005 has been waived.

(d)          Section 5.01(f) of the Agreement is deleted and replaced with the following:

“(f)           Stock and Assets of Subsidiaries.  Unless the prior written consent of Lender is obtained,
                             Borrower will not create, incur or assume or suffer to be incurred or to exist any lien on any of the common
                             stock of LGC, Laclede Energy, or any other Subsidiary, or on the inventory or accounts receivable of LGC.”

3.           Release of Guaranty of SM&P.  Lender hereby releases the Guaranty dated as of August 4, 2005, executed by SM&P in favor of Lender and acknowledges that as of the effective date of this Agreement, SM&P shall no longer be a Guarantor of Borrower’s Obligations.

 
 
 


4.           Costs and Expenses.  Borrower hereby agrees to reimburse Lender upon demand for all out-of-pocket costs and expenses (including, without limitation, reasonable attorneys’ fees and expenses) incurred by Lender in the preparation, negotiation and execution of this Amendment and any and all other agreements, documents, instruments and/or certificates relating to the amendment of Borrower’s existing credit facilities with Lender.  All of the obligations of Borrower under this paragraph shall survive the payment of Borrower’s Obligations and the termination of the Agreement.

5.           References to Agreement.  All references in the Agreement to “this Agreement” and any other references of similar import shall henceforth mean the Agreement as amended by this Amendment.

6.           Full Force and Effect.  Except to the extent specifically amended by this Amendment, all of the terms, provisions, conditions, covenants, representations and warranties contained in the Agreement and the Note shall be and remain in full force and effect and the same are hereby ratified and confirmed.

7.           Benefit.  This Amendment shall be binding upon and inure to the benefit of Borrower and Lender and their respective successors and assigns, except that Borrower may not assign, transfer or delegate any of its rights or obligations under the Agreement as amended by this Amendment.

8.           Representations and Warranties.  Borrower hereby represents and warrants to Lender that:

(a)           the execution, delivery and performance by Borrower of this Amendment are within the corporate powers of Borrower, have been duly authorized by all necessary corporate action and require no action by or in respect of, consent of or filing or recording with, any governmental or regulatory body, instrumentality, authority, agency or official or any other Person;

(b)           the execution, delivery and performance by Borrower of this Amendment do not conflict with, or result in a breach of the terms, conditions or provisions of, or constitute a default under or result in any violation of, the terms of the Articles of Incorporation or Bylaws of Borrower, any applicable law, rule, regulation, order, writ, judgment or decree of any court or governmental or regulatory body, instrumentality authority, agency or official or any agreement, document or instrument to which Borrower is a party or by which Borrower or any of its property is bound or to which Borrower or any of its property is subject;

(c)           this Amendment has been duly executed and delivered by Borrower and constitutes the legal, valid and binding obligation of Borrower enforceable against Borrower in accordance with its terms, except as such enforceability may be limited by (i) applicable bankruptcy, insolvency or similar laws affecting the enforcement of creditors’ rights generally and (ii) general principles of equity (regardless of whether such enforceability is considered in a proceeding in equity or at law);

(d)           all of the representations and warranties made by Borrower in the Agreement and/or in any of the other Transaction Documents are true and correct in all material respects on and as of the date of this Amendment as if made on and as of the date of this Amendment; and

(e)           as of the date of this Amendment, no Default or Event of Default under or within the meaning of the Agreement has occurred and is continuing.

 
- 2 - -
 
 

9.            Release.  Borrower hereby unconditionally releases, acquits, waives, and forever discharges Lender and its successors, assigns, directors, officers, agents, employees, representatives and attorneys from any and all liabilities, claims, causes of action or defenses, if any, and for any action taken or for any failure to take any action, existing at any time prior to the execution of this Amendment.

10.           Inconsistency.  In the event of any inconsistency or conflict between this Amendment, the Agreement, the terms, provisions and conditions contained in this Amendment shall govern and control.

11.           Missouri Law.  This Amendment shall be governed by and construed in accordance with the substantive laws of the State of Missouri (without reference to conflict of law principles).

12.           Notice Required by Section 432.047 R.S. Mo.  ORAL AGREEMENTS OR COMMITMENTS TO LOAN MONEY, EXTEND CREDIT OR TO FORBEAR FROM ENFORCING REPAYMENT OF A DEBT INCLUDING PROMISES TO EXTEND OR RENEW SUCH DEBT ARE NOT ENFORCEABLE. TO PROTECT YOU (BORROWER(S)) AND US (CREDITOR) FROM MISUNDERSTANDING OR DISAPPOINTMENT, ANY AGREEMENTS WE REACH COVERING SUCH MATTERS ARE CONTAINED IN THIS WRITING WHICH IS THE COMPLETE AND EXCLUSIVE STATEMENT OF THE AGREEMENT BETWEEN US, EXCEPT AS WE MAY LATER AGREE IN WRITING TO MODIFY IT.

13.           Conditions Precedent.  Notwithstanding any provision contained in this Amendment to the contrary, this Amendment shall not be effective unless and until Lender shall have received the following, all in form and substance acceptable to Lender:

(a)           this Amendment, duly executed by Borrower;

(b)           a Consent of Guarantor duly executed by Laclede Energy;

(c)           the following organizational documents of Borrower:  (i) a copy of resolutions of the Board of Directors of Borrower, duly adopted, which authorize the execution, delivery and performance of this Amendment; (ii) an incumbency certificate, executed by the Secretary of Borrower, which shall identify by name and title and bear the signatures of all of the officers of Borrower executing this Amendment; and (iii) a certificate of corporate good standing of Borrower issued by the Secretary of State of the State of Missouri, or other evidence of good standing satisfactory to Lender;

(d)           the following organizational documents of Laclede Energy:  (i) a copy of resolutions of the Board of Directors of Laclede Energy, duly adopted, which authorize the execution, delivery and performance of the Consent of Guarantor; (ii) an incumbency certificate, executed by the Secretary of Laclede Energy, which shall identify by name and title and bear the signatures of all of the officers of Borrower executing the Consent of Guarantor; and (iii) a certificate of corporate good standing of Laclede Energy issued by the Secretary of State of the State of Missouri, or other evidence of good standing satisfactory to Lender; and

(e)           such other documents and information as reasonably requested by Lender.

IN WITNESS WHEREOF, Borrower and Lender have executed this Amendment as of the day and year first above written.
 
(SIGNATURES ON FOLLOWING PAGE)

 
- 3 - -
 
 

SIGNATURE PAGE-
FIRST AMENDMENT TO AMENDED AND RESTATED REVOLVING CREDIT AGREEMENT




     
 
Borrower:
     
 
THE LACLEDE GROUP, INC.
     
 
By:
/s/ Lynn D. Rawlings
     
 
Name:
Lynn D. Rawlings
     
 
Title:
Treasurer and Assistant Secretary
     
     
 
Lender:
   
 
U.S. BANK NATIONAL ASSOCIATION,
 
formerly known as Firstar Bank, N.A.
     
 
By:
/s/ Karen Meyer
   
Karen Meyer, Vice President


 
- 4 - -
 
 

EX-12 10 ex12.htm EXHIBIT 12 RATIO OF EARNINGS ex12.htm

Exhibit 12

THE LACLEDE GROUP, INC. AND SUBSIDIARY COMPANIES
 
SCHEDULE OF COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
 
 
   
Twelve Months Ended
 
   
March 31,
     
September 30,
 
(Thousands of Dollars)
   
2008
       
2007
   
2006
   
2005
   
2004
   
2003
 
                                           
Income from continuing
    operations before interest
                                         
    charges and income taxes
 
$
112,226
     
$
101,866
 
$
100,079
 
$
78,677
 
$
78,605
 
$
81,532
 
Add: One third of applicable
                                         
    rentals charged to operating
                                         
    expense (which approximates
                                         
    the interest factor)
   
1,612
       
1,485
   
1,291
   
938
   
538
   
457
 
          Total Earnings
 
$
113,838
     
$
103,351
 
$
101,370
 
$
79,615
 
$
79,143
 
$
81,989
 
                                           
                                           
Interest on long-term debt –
                                         
    Laclede Gas
 
$
21,252
     
$
22,503
 
$
22,328
 
$
22,836
 
$
22,010
 
$
20,169
 
Other interest
   
11,277
       
11,431
   
10,555
   
4,418
   
3,511
   
3,971
 
Add: One third of applicable
                                         
    rentals charged to operating
                                         
    expense (which approximates
                                         
    the interest factor)
   
1,612
       
1,485
   
1,291
   
938
   
538
   
457
 
          Total Fixed Charges
 
$
34,141
     
$
35,419
 
$
34,174
 
$
28,192
 
$
26,059
 
$
24,597
 
                                           
                                           
Ratio of Earnings to Fixed
                                         
    Charges
   
3.33
       
2.92
   
2.97
   
2.82
   
3.04
   
3.33
 
                                           
                                           
                                           



 
 
 
 


LACLEDE GAS COMPANY
 
SCHEDULE OF COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
 
 
   
Twelve Months Ended
 
   
March 31,
     
September 30,
 
(Thousands of Dollars)
   
2008
       
2007
   
2006
   
2005
   
2004
   
2003
 
                                           
Income before interest
                                         
    charges and income taxes
 
$
85,727
     
$
80,134
 
$
72,077
 
$
72,092
 
$
73,956
 
$
76,274
 
Add: One third of applicable
                                         
    rentals charged to operating
                                         
    expense (which approximates
                                         
    the interest factor)
   
1,612
       
1,485
   
1,291
   
938
   
538
   
457
 
          Total Earnings
 
$
87,339
     
$
81,619
 
$
73,368
 
$
73,030
 
$
74,494
 
$
76,731
 
                                           
                                           
Interest on long-term debt
 
$
21,252
     
$
22,502
 
$
22,329
 
$
22,835
 
$
22,010
 
$
20,169
 
Other interest
   
11,489
       
11,101
   
10,236
   
4,076
   
3,192
   
3,752
 
Add: One third of applicable
                                         
    rentals charged to operating
                                         
    expense (which approximates
                                         
    the interest factor)
   
1,612
       
1,485
   
1,291
   
938
   
538
   
457
 
          Total Fixed Charges
 
$
34,353
     
$
35,088
 
$
33,856
 
$
27,849
 
$
25,740
 
$
24,378
 
                                           
                                           
Ratio of Earnings to Fixed
                                         
    Charges
   
2.54
       
2.33
   
2.17
   
2.62
   
2.89
   
3.15
 
                                           
                                           
                                           


 
 
 
 

EX-31 11 ex31.htm EXHIBIT 31 CERTIFICATIONS ex31.htm


Exhibit 31
 
CERTIFICATION
 
I, Douglas H. Yaeger, certify that:
 
1.
I have reviewed this quarterly report on Form 10-Q of The Laclede Group, Inc.;
   
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 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:
 
April 23, 2008
Signature:
 
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board,
         
President and Chief
         
Executive Officer
 

 
 
 
 


CERTIFICATION
 
I, Mark D. Waltermire, certify that:
 
1.
I have reviewed this quarterly report on Form 10-Q of The Laclede Group, Inc.;
   
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 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:
 
April 23, 2008
Signature:
 
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Chief Financial Officer
           
           
 
 

 
 
 
 



CERTIFICATION
 
I, Douglas H. Yaeger, certify that:
 
1.
I have reviewed this quarterly report on Form 10-Q of Laclede Gas Company;
   
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 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:
 
April 23, 2008
Signature:
 
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board,
         
President and Chief
         
Executive Officer
 


 
 
 
 


 
CERTIFICATION
 
I, Mark D. Waltermire, certify that:
 
1.
I have reviewed this quarterly report on Form 10-Q of Laclede Gas Company;
   
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 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:
 
April 23, 2008
Signature:
 
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Senior Vice President and
         
    Chief Financial Officer
 

 
 
 
 

EX-32 12 ex32.htm EXHIBIT 32 CERTIFICATIONS ex32.htm


Exhibit 32

Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Douglas H. Yaeger, Chairman of the Board, President and Chief Executive Officer of The Laclede Group, Inc., hereby certify that

 
(a)
To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2008 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and
     
 
(b)
To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the quarter ended March 31, 2008 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.


Date:
 
April 23, 2008
   
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board, President
         
and Chief Executive Officer
           


 
 
 
 


Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Mark D. Waltermire, Chief Financial Officer of The Laclede Group, Inc., hereby certify that

 
(a)
To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2008 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and
     
 
(b)
To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the quarter ended March 31, 2008 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.

Date:
 
April 23, 2008
   
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Chief Financial Officer
           
           


 
 
 
 


Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Douglas H. Yaeger, Chairman of the Board, President and Chief Executive Officer of Laclede Gas Company, hereby certify that

 
(a)
To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2008 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and
     
 
(b)
To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the quarter ended March 31, 2008 fairly presents, in all material respects, the financial condition and results of operations of  Laclede Gas Company.

Date:
 
April 23, 2008
   
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board, President
         
and Chief Executive Officer
           


 
 
 
 


Section 1350 Certification

Pursuant to 18 U.S.C. Section 1350, as adopted pursuant to §906 of the Sarbanes-Oxley Act of 2002, I, Mark D. Waltermire, Senior Vice President and Chief Financial Officer of Laclede Gas Company, hereby certify that

 
(a)
To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2008 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and
     
 
(b)
To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the quarter ended March 31, 2008 fairly presents, in all material respects, the financial condition and results of operations of  Laclede Gas Company.

Date:
 
April 23, 2008
   
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Senior Vice President and
         
    Chief Financial Officer
           


 
 
 
 

EX-99.1 13 ex99-1.htm LACLEDE GAS COMPANY MARCH 31, 2008 10-Q ex99-1.htm

Exhibit 99.1


LACLEDE GAS COMPANY
STATEMENTS OF INCOME
(UNAUDITED)
   
   
Three Months Ended
     
Six Months Ended
 
   
March 31,
     
March 31,
 
(Thousands)
   
2008
   
2007
       
2008
   
2007
 
                               
Operating Revenues:
                             
  Utility
 
$
507,089
 
$
493,593
     
$
827,981
 
$
842,081
 
  Other
   
740
   
778
       
1,526
   
1,440
 
          Total Operating Revenues
   
507,829
   
494,371
       
829,507
   
843,521
 
                               
Operating Expenses:
                             
  Utility
                             
      Natural and propane gas
   
377,526
   
373,576
       
600,367
   
625,099
 
      Other operation expenses
   
38,989
   
36,816
       
74,202
   
70,496
 
      Maintenance
   
5,814
   
6,060
       
12,049
   
11,658
 
      Depreciation and amortization
   
8,763
   
8,568
       
17,476
   
17,065
 
      Taxes, other than income taxes
   
29,255
   
28,348
       
45,936
   
47,107
 
          Total Utility Operating Expenses
   
460,347
   
453,368
       
750,030
   
771,425
 
      Other
   
805
   
784
       
1,530
   
1,435
 
          Total Operating Expenses
   
461,152
   
454,152
       
751,560
   
772,860
 
Operating Income
   
46,677
   
40,219
       
77,947
   
70,661
 
Other Income and (Income Deductions) – Net
   
(523
)
 
458
       
1,509
   
3,201
 
Interest Charges:
                             
  Interest on long-term debt
   
4,875
   
5,625
       
10,001
   
11,251
 
  Other interest charges
   
2,720
   
2,927
       
6,736
   
6,347
 
          Total Interest Charges
   
7,595
   
8,552
       
16,737
   
17,598
 
Income Before Income Taxes
   
38,559
   
32,125
       
62,719
   
56,264
 
Income Tax Expense
   
13,259
   
11,407
       
21,624
   
19,871
 
Net Income
   
25,300
   
20,718
       
41,095
   
36,393
 
Dividends on Redeemable Preferred Stock
   
9
   
11
       
19
   
23
 
Earnings Applicable to Common Stock
 
$
25,291
 
$
20,707
     
$
41,076
 
$
36,370
 
                               
                               
See Notes to Financial Statements.
                             


 
 
 
 
 
 
 
 
 
 


 
1
 
 

LACLEDE GAS COMPANY
STATEMENTS OF COMPREHENSIVE INCOME
(UNAUDITED)


 
   
Three Months Ended
     
Six Months Ended
 
   
March 31,
     
March 31,
 
(Thousands)
   
2008
   
2007
       
2008
   
2007
 
                               
Net Income
 
$
25,300
 
$
20,718
     
$
41,095
 
$
36,393
 
Other Comprehensive Income (Loss), Before Tax:
                             
  Amortization of actuarial loss included in net periodic
                             
    pension cost
   
43
   
       
86
   
 
Income Tax Expense Related to Items of Other
                             
  Comprehensive Income
   
16
   
       
33
   
 
Other Comprehensive Income, Net of Tax
   
27
   
       
53
   
 
Comprehensive Income
 
$
25,327
 
$
20,718
     
$
41,148
 
$
36,393
 
                               
                               
See Notes to Financial Statements.
                             
















 
2
 
 

LACLEDE GAS COMPANY
BALANCE SHEETS
(UNAUDITED)
 
                       
   
March 31,
     
Sept. 30,
     
March 31,
 
(Thousands)
 
2008
     
2007
     
2007
 
                             
ASSETS
                           
Utility Plant
 
$
1,204,984
     
$
1,187,828
     
$
1,165,232
 
  Less:  Accumulated depreciation and amortization
   
398,661
       
394,034
       
388,775
 
      Net Utility Plant
   
806,323
       
793,794
       
776,457
 
Other Property and Investments
   
37,585
       
36,933
       
36,323
 
                             
Current Assets:
                           
  Cash and cash equivalents
   
4,850
       
2,454
       
4,976
 
  Accounts receivable:
                           
    Gas customers – billed and unbilled
   
190,298
       
102,224
       
153,538
 
    Associated companies
   
204
       
253
       
226
 
    Other
   
35,015
       
8,973
       
45,424
 
    Allowances for doubtful accounts
   
(13,478
)
     
(10,961
)
     
(13,966
)
  Delayed customer billings
   
40,417
       
       
36,377
 
  Inventories:
                           
    Natural gas stored underground at LIFO cost
   
31,730
       
138,198
       
43,940
 
    Propane gas at FIFO cost
   
19,904
       
19,950
       
19,951
 
    Materials, supplies, and merchandise at average cost
   
5,283
       
4,864
       
5,774
 
  Derivative instrument assets
   
13,773
       
26,296
       
16,764
 
  Unamortized purchased gas adjustments
   
4,365
       
12,813
       
17,990
 
  Deferred income taxes
   
4,114
       
275
       
3,781
 
  Prepayments and other
   
5,469
       
6,970
       
5,552
 
      Total Current Assets
   
341,944
       
312,309
       
340,327
 
                             
Deferred Charges:
                           
  Prepaid pension cost
   
       
       
58,240
 
  Regulatory assets
   
265,495
       
285,054
       
155,786
 
  Other
   
4,836
       
3,113
       
4,693
 
      Total Deferred Charges
   
270,331
       
288,167
       
218,719
 
Total Assets
 
$
1,456,183
     
$
1,431,203
     
$
1,371,826
 
                             


 
 
 
 
 
 
 
 
 
 
 
 

 
3
 
 


LACLEDE GAS COMPANY
BALANCE SHEETS (Continued)
(UNAUDITED)


 
   
March 31,
     
Sept. 30,
     
March 31,
 
(Thousands, except share amounts)
 
2008
     
2007
     
2007
 
                             
CAPITALIZATION AND LIABILITIES
                           
Capitalization:
                           
  Common stock and Paid-in capital (10,365, 10,307, and
    10,252 shares issued, respectively)
 
$
154,560
     
$
151,510
     
$
148,599
 
  Retained earnings
   
220,917
       
195,728
       
215,442
 
  Accumulated other comprehensive loss
   
(1,674
)
     
(1,727
)
     
(834
)
      Total Common Stock Equity
   
373,803
       
345,511
       
363,207
 
  Redeemable preferred stock (less current sinking fund
    requirements)
   
467
       
627
       
627
 
  Long-term debt (less current portion)
   
309,152
       
309,122
       
309,082
 
      Total Capitalization
   
683,422
       
655,260
       
672,916
 
                             
Current Liabilities:
                           
  Notes payable
   
171,650
       
211,400
       
117,050
 
  Accounts payable
   
92,422
       
45,084
       
80,034
 
  Accounts payable – associated companies
   
4,563
       
4,065
       
12,078
 
  Advance customer billings
   
       
25,440
       
 
  Current portion of long-term debt and preferred stock
   
160
       
40,160
       
40,160
 
  Wages and compensation accrued
   
11,880
       
11,532
       
11,175
 
  Dividends payable
   
8,306
       
7,974
       
7,964
 
  Customer deposits
   
13,960
       
15,899
       
15,678
 
  Interest accrued
   
9,888
       
10,806
       
10,621
 
  Taxes accrued
   
33,345
       
19,210
       
45,793
 
  Other
   
6,804
       
5,342
       
6,156
 
      Total Current Liabilities
   
352,978
       
396,912
       
346,709
 
                             
Deferred Credits and Other Liabilities:
                           
  Deferred income taxes
   
234,122
       
223,192
       
219,871
 
  Unamortized investment tax credits
   
4,086
       
4,200
       
4,318
 
  Pension and postretirement benefit costs
   
67,515
       
63,678
       
22,182
 
  Asset retirement obligations
   
26,835
       
26,054
       
25,496
 
  Regulatory liabilities
   
64,027
       
39,589
       
58,058
 
  Other
   
23,198
       
22,318
       
22,276
 
      Total Deferred Credits and Other Liabilities
   
419,783
       
379,031
       
352,201
 
Total Capitalization and Liabilities
 
$
1,456,183
     
$
1,431,203
     
$
1,371,826
 
                             
                             
                             
See Notes to Financial Statements.
                           


 
 
 

 
4
 
 


LACLEDE GAS COMPANY
STATEMENTS OF CASH FLOWS
(UNAUDITED)
 
   
Six Months Ended
 
   
March 31,
 
(Thousands)
 
2008
     
2007
 
                   
Operating Activities:
                 
  Net Income
 
$
41,095
     
$
36,393
 
  Adjustments to reconcile net income to net cash
    provided by (used in) operating activities:
                 
      Depreciation and amortization
   
17,476
       
17,065
 
      Deferred income taxes and investment tax credits
   
(2,971
)
     
(19,985
)
      Other – net
   
1,097
       
535
 
      Changes in assets and liabilities:
                 
        Accounts receivable – net
   
(111,550
)
     
(87,000
)
        Unamortized purchased gas adjustments
   
8,448
       
26,391
 
        Deferred purchased gas costs
   
53,094
       
64,706
 
        Accounts payable
   
47,836
       
36,347
 
        Delayed customer billings - net
   
(65,857
)
     
(67,820
)
        Taxes accrued
   
14,135
       
30,248
 
        Natural gas stored underground
   
106,468
       
93,477
 
        Other assets and liabilities
   
13,300
       
2,413
 
          Net cash provided by operating activities
   
122,571
       
132,770
 
                   
Investing Activities:
                 
  Capital expenditures
   
(26,407
)
     
(26,149
)
  Other investments
   
237
       
(21
)
           Net cash used in investing activities
   
(26,170
)
     
(26,170
)
                   
Financing Activities:
                 
  Maturity of first mortgage bonds
   
(40,000
)
     
 
  Repayment of short-term debt – net
   
(39,750
)
     
(90,250
)
  Dividends paid
   
(16,079
)
     
(15,466
)
  Issuance of common stock to Laclede Group
   
1,967
       
1,877
 
  Preferred stock reacquired
   
(160
)
     
(159
)
  Other
   
17
       
60
 
          Net cash used in financing activities
   
(94,005
)
     
(103,938
)
                   
Net Increase in Cash and Cash Equivalents
   
2,396
       
2,662
 
Cash and Cash Equivalents at Beginning of Period
   
2,454
       
2,314
 
Cash and Cash Equivalents at End of Period
 
$
4,850
     
$
4,976
 
                   
                   
Supplemental Disclosure of Cash Paid (Refunded) During the Period for:
                 
    Interest
 
$
17,880
     
$
16,828
 
    Income taxes
   
6,925
       
(14,043
)
                   
                   
See Notes to Financial Statements.
                 

 
 

 
5
 
 

LACLEDE GAS COMPANY
NOTES TO FINANCIAL STATEMENTS


1.
SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

These notes are an integral part of the accompanying financial statements of Laclede Gas Company (Laclede Gas or the Utility). In the opinion of Laclede Gas, this interim report includes all adjustments (consisting of only normal recurring accruals) necessary for the fair presentation of the results of operations for the periods presented. This Form 10-Q should be read in conjunction with the Notes to Financial Statements contained in Laclede Gas’ Fiscal Year 2007 Form 10-K.
Laclede Gas is a regulated natural gas distribution utility having a material seasonal cycle. As a result, these interim statements of income for Laclede Gas are not necessarily indicative of annual results or representative of succeeding quarters of the fiscal year. Due to the seasonal nature of the business of Laclede Gas, earnings are typically concentrated in the November through April period, which generally corresponds with the heating season.
BASIS OF PRESENTATION - In compliance with generally accepted accounting principles, transactions between Laclede Gas and its affiliates as well as intercompany balances on Laclede Gas’ Balance Sheet have not been eliminated from the Laclede Gas financial statements.
Laclede Gas provides administrative and general support to affiliates. All such costs, which are not material, are billed to the appropriate affiliates. Also, Laclede Group may charge or reimburse Laclede Gas for certain tax-related amounts. Unpaid balances relating to these activities are reflected in the Laclede Gas Balance Sheets as Accounts Receivable-Associated Companies or as Accounts Payable-Associated Companies. Additionally, Laclede Gas may, on occasion, borrow funds from or lend funds to affiliated companies. Unpaid balances relating to these arrangements, if any, are reflected in Notes Receivable-Associated Companies or Notes Payable-Associated Companies.
REVENUE RECOGNITION - Laclede Gas reads meters and bills its customers on monthly cycles. The Utility records its utility operating revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at March 31, 2008 and 2007, for the Utility, were $31.9 million and $18.5 million, respectively. The amount of accrued unbilled revenue at September 30, 2007 was $11.9 million.
INCOME TAXES - Laclede Gas has elected, for tax purposes only, various accelerated depreciation provisions of the Internal Revenue Code. In addition, certain other costs are expensed currently for tax purposes while being deferred for book purposes. Effective October 1, 2007, generally accepted accounting principles require that tax benefits be recognized in the financial statements as determined by new recognition and measurement provisions. These provisions permit the benefit from a tax position to be recognized only if, and to the extent that, it is more likely than not that the tax position will be sustained upon examination by the taxing authority, based on the technical merits of the position. Unrecognized tax benefits and related interest and penalties, if any, are recorded as liabilities or as a reduction to deferred tax assets. Laclede Gas records deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the carrying amounts of assets and liabilities in the financial statements, and the related tax basis. Changes in enacted tax rates, if any, and certain property basis differences will be reflected by entries to regulatory asset or liability accounts.
Laclede Gas’ investment tax credits utilized prior to 1986 have been deferred and are being amortized in accordance with regulatory treatment over the useful life of the related property.
Laclede Group files a consolidated federal income tax return and allocates income taxes to Laclede Gas and its other subsidiaries as if each entity were a separate taxpayer.
GROSS RECEIPTS TAXES - Gross receipts taxes associated with Laclede Gas’ natural gas utility service are imposed on the Utility and billed to its customers. These amounts are recorded gross in the Statements of Income. Amounts recorded in Utility Operating Revenues for the quarters ended March 31, 2008 and 2007 were $25.2 million and $24.1 million, respectively. Amounts recorded in Utility Operating Revenues for the six months ended March 31, 2008 and 2007 were $38.2 million and $38.8 million, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes Other Than Income line.
STOCK-BASED COMPENSATION – Officers and employees of Laclede Gas, as determined by the Compensation Committee of Laclede Group’s Board of Directors, are eligible to be selected for awards under the Laclede Group 2006 Equity Incentive Plan. For Laclede Group’s non-employee directors, shares are awarded under the Restricted Stock Plan for Non-Employee Directors. Refer to Note 1 of the Financial Statements included in the Utility’s Form 10-K for the fiscal year ended September 30, 2007 for descriptions of these plans. For awards made to its employees, the Utility records its allocation of compensation cost from Laclede Group with a corresponding increase to additional paid-in capital.

 
6
 
 


The amounts of compensation cost allocated to the Utility for share-based compensation arrangements are presented below:

     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Total compensation cost
 
$
628
 
$
576
 
$
1,168
 
$
1,044
 
 
Compensation cost capitalized
   
(162
)
 
(143
)
 
(297
)
 
(261
)
 
Compensation cost recognized in net income
   
466
   
433
   
871
   
783
 
 
Income tax benefit recognized in net income
   
(181
)
 
(167
)
 
(337
)
 
(302
)
 
Compensation cost recognized in net income,
                         
 
  net of income tax
 
$
285
 
$
266
 
$
534
 
$
481
 

As of March 31, 2008, there was $4.5 million in unrecognized compensation cost related to nonvested share-based compensation arrangements (options and restricted stock) that is expected to be allocated to the Utility over a weighted average period of 2.5 years.
NEW ACCOUNTING STANDARDS – In June 2006, the Financial Accounting Standards Board (FASB) issued Interpretation Number 48 (FIN 48), “Accounting for Uncertainty in Income Taxes.” FIN 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with FASB Statement No. 109, “Accounting for Income Taxes.” Under FIN 48, Laclede Gas may recognize the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position. The tax benefits recognized in the financial statements from such a position should be measured based on the largest benefit that has a greater than fifty percent likelihood of being realized upon settlement with the taxing authorities. FIN 48 also provides guidance on derecognition, classification, interest and penalties, accounting in interim periods, disclosure, and transition. Laclede Gas adopted the provisions of FIN 48 as of October 1, 2007. For details regarding the cumulative effect of adoption and other pertinent information, see Note 3, Income Taxes.
In September 2006, the FASB issued Statement of Financial Accounting Standards (SFAS) No. 157, “Fair Value Measurements.” This Statement defines fair value, establishes a framework for measuring fair value in generally accepted accounting principles, and expands disclosures about fair value measurements. The Statement applies to fair value measurements required under other accounting guidance that require or permit fair value measurements. Accordingly, this Statement does not require any new fair value measurements. The guidance in this Statement does not apply to the Laclede Group’s stock-based compensation plans accounted for in accordance with SFAS No. 123(R), “Share-Based Payment.” Except as described below, SFAS No. 157 is effective for the Utility as of the beginning of fiscal year 2009. In February 2008, the FASB issued two Staff Positions that amend SFAS No. 157. The first FASB Staff Position (FSP), No. FAS 157-1, excludes from the scope of SFAS No. 157 accounting pronouncements that address fair value measurements for purposes of lease classification and measurement. The second FSP, No. FAS 157-2, delays the effective date of SFAS No. 157 for nonfinancial assets and nonfinancial liabilities, except for items that are recognized or disclosed at fair value in the financial statements on a recurring basis (at least annually). Application of SFAS No. 157 to these items will be effective for Laclede Gas as of the beginning of fiscal year 2010. The Utility is currently evaluating the potential impact of this Statement, as amended by these Staff Positions, on its financial statements.
In September 2006, the FASB issued SFAS No. 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans.” As discussed in Note 2 to the Financial Statements included in the Utility’s Fiscal Year 2007 Form 10-K, Laclede Gas adopted the recognition and disclosure provisions of this Statement effective September 30, 2007. The Statement also requires that plan assets and benefit obligations be measured as of the date of the employer’s fiscal year-end statement of financial position. This requirement is effective for the Utility as of the end of fiscal year 2009. In conjunction with adoption of this provision of SFAS No. 158, the Utility will be required to change its valuation date for its pension and other postretirement plans from June 30 to September 30. The Utility is currently evaluating the impact of adoption of the change in measurement date on its financial statements.
In February 2007, the FASB issued SFAS No. 159, “The Fair Value Option for Financial Assets and Financial Liabilities.” The Statement permits entities to choose to measure many financial instruments and certain other items at fair value that are not currently required to be measured at fair value. SFAS No. 159 also establishes presentation and disclosure requirements designed to facilitate comparisons between entities that choose different measurement attributes for similar types of assets and liabilities. This Statement does not affect any existing accounting literature that requires certain assets and liabilities to be carried at fair value. Upon adoption of SFAS No. 159, entities are permitted to choose, at specified election dates, to measure eligible items at fair value (fair value option). Unrealized gains and losses on items for which the fair value option has been elected are reported in earnings at each reporting date. The decision about whether to elect the fair value option is applied instrument by instrument with few exceptions. The decision is also

 
7
 
 

irrevocable (unless a new election date occurs) and must be applied to entire instruments and not to portions of instruments. SFAS No. 159 requires that cash flows related to items measured at fair value be classified in the statement of cash flows according to their nature and purpose as required by SFAS No. 95, “Statement of Cash Flows” (as amended). SFAS No. 159 is effective for the Utility as of the beginning of fiscal year 2009. Laclede Gas is currently evaluating the provisions of this Statement.
In June 2007, the FASB ratified the consensus reached in Emerging Issues Task Force (EITF) Issue No. 06-11, “Accounting for Income Tax Benefits of Dividends on Share-Based Payment Awards.” This Issue addresses how an entity should recognize the tax benefit received on dividends that are (a) paid to employees holding equity-classified nonvested shares, equity-classified nonvested share units, or equity-classified outstanding share options and (b) charged to retained earnings under SFAS No. 123(R). The Task Force reached a consensus that such tax benefits should be recognized as an increase in additional paid-in capital. This EITF Issue also addresses how the accounting for these tax benefits is affected if an entity’s estimate of forfeitures changes in subsequent periods. This EITF Issue is effective for Laclede Gas as of the beginning of fiscal year 2009. The Utility is currently evaluating the provisions of this EITF Issue.
In December 2007, the FASB issued SFAS No. 160, “Noncontrolling Interests in Consolidated Financial Statements.” This Statement amends Accounting Research Bulletin No. 51, “Consolidated Financial Statements.” A noncontrolling interest, sometimes called a minority interest, is the portion of equity in a subsidiary not attributable, directly or indirectly, to a parent. SFAS No. 160 clarifies that noncontrolling interests should be separately reported as equity in the balance sheet. Additionally, SFAS No. 160 requires certain changes in presentation to income statements. SFAS No. 160 also addresses accounting for changes in the parent’s ownership interest of a subsidiary, accounting for the deconsolidation of a subsidiary, and disclosure requirements. This Statement is effective for Laclede Gas as of the beginning of fiscal year 2010. Currently, Laclede Gas does not have any subsidiaries and therefore adoption of this Statement is not expected to have any effect on the Utility’s financial statements.
In December 2007, the FASB issued SFAS No. 141 (revised 2007) (141(R)), “Business Combinations.” This Statement revises SFAS No. 141 but retains the fundamental requirements in SFAS No. 141 that the acquisition method (formerly known as purchase method) of accounting be used for all business combinations. SFAS No. 141(R) requires an acquirer to recognize the assets acquired, the liabilities assumed, and any noncontrolling interest in the acquiree at the acquisition date, measured at their fair values as of that date, with limited exceptions specified in the Statement. SFAS 141(R) requires acquisition-related costs to be accounted for separately instead of being allocated to the assets acquired and liabilities assumed. SFAS No. 141(R) also amends the guidance related to the recognition of certain assets acquired and liabilities assumed that relate to contingencies, research and development assets acquired that have no alternative future use, and negative goodwill arising from a bargain purchase. Laclede Gas is required to adopt SFAS No. 141(R) prospectively to business combinations with acquisition dates on or after October 1, 2009 (fiscal 2010). Because this Statement is only applicable to future business combinations, existing amounts reported on the Utility’s financial statements will not be impacted by adoption of this Statement.
In March 2008, the FASB issued SFAS No. 161, “Disclosures about Derivative Instruments and Hedging Activities.” This Statement amends SFAS No. 133, “Accounting for Derivative Instruments and Hedging Activities,” by requiring enhanced disclosures about (a) how and why an entity uses derivative instruments, (b) how derivative instruments and related hedged items are accounted for under Statement 133 and its related interpretations, and (c) how derivative instruments and related hedged items affect an entity’s financial position, financial performance, and cash flows. This Statement will be effective for Laclede Gas’s interim and annual financial statements beginning in fiscal year 2010. This Statement encourages, but does not require, comparative disclosures for earlier periods at initial adoption. The Utility is currently evaluating the provisions of this Statement.


2.
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

Laclede Gas has non-contributory defined benefit, trusteed forms of pension plans covering substantially all employees over the age of twenty-one. Benefits are based on years of service and the participant’s compensation during the highest three years of the last ten years of employment. Plan assets consist primarily of corporate and U.S. government obligations and pooled equity funds.
Pension costs for the quarters ending March 31, 2008 and 2007 were $1.5 million and $1.4 million, respectively, including amounts charged to construction. Pension costs for the six months ended March 31, 2008 and 2007 were $3.1 million and $2.7 million, respectively, including amounts charged to construction.


 
8
 
 


The net periodic pension costs include the following components:

     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Service cost – benefits earned
                         
 
during the period
 
$
3,243
 
$
3,105
 
$
6,485
 
$
6,211
 
 
Interest cost on projected
                         
 
benefit obligation
   
4,670
   
4,483
   
9,340
   
8,965
 
 
Expected return on plan assets
   
(5,163
)
 
(5,074
)
 
(10,325
)
 
(10,148
)
 
Amortization of prior service cost
   
272
   
283
   
544
   
567
 
 
Amortization of actuarial loss
   
791
   
921
   
1,582
   
1,841
 
 
Sub-total
   
3,813
   
3,718
   
7,626
   
7,436
 
 
Loss on lump sum settlement
   
   
945
   
   
945
 
 
Regulatory adjustment
   
(2,280
)
 
(3,309
)
 
(4,560
)
 
(5,673
)
 
Net pension cost
 
$
1,533
 
$
1,354
 
$
3,066
 
$
2,708
 

Pursuant to the provisions of the Laclede Gas pension plans, pension obligations may be satisfied by lump-sum cash payments. Pursuant to a Missouri Public Service Commission (MoPSC or Commission) Order, lump-sum payments are recognized as settlements (which can result in gains or losses) only if the total of such payments exceeds 100% of the sum of service and interest costs. No lump sum payments were recognized as settlements during the six months ended March 31, 2008. Lump sum payments recognized as settlements during the six months ended March 31, 2007 were $2.8 million.
Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains or losses not yet includible in pension cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the projected benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. The recovery in rates for the Utility’s qualified pension plans is based on an allowance of $4.1 million annually effective October 1, 2005 and $4.8 million annually effective August 1, 2007. The difference between this amount and pension expense as calculated pursuant to the above and that otherwise would be included in the Statements of Income and Comprehensive Income is deferred as a regulatory asset or regulatory liability.
Laclede Gas provides certain life insurance benefits at retirement. Medical insurance is available after early retirement until age 65. The transition obligation not yet includible in postretirement benefit cost is being amortized over 20 years. Postretirement benefit costs for the quarters ended March 31, 2008 and 2007 were $1.9 million and $2.0 million, respectively, including amounts charged to construction. Postretirement benefit costs for the six months ended March 31, 2008 and 2007 were $3.8 million and $3.9 million, respectively, including amounts charged to construction.
Net periodic postretirement benefit costs consisted of the following components:

     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Service cost – benefits earned
                         
 
during the period
 
$
1,140
 
$
1,015
 
$
2,280
 
$
2,031
 
 
Interest cost on accumulated
                         
 
postretirement benefit obligation
   
977
   
900
   
1,954
   
1,800
 
 
Expected return on plan assets
   
(509
)
 
(431
)
 
(1,019
)
 
(862
)
 
Amortization of transition obligation
   
34
   
34
   
68
   
68
 
 
Amortization of prior service cost
   
(582
)
 
(582
)
 
(1,164
)
 
(1,164
)
 
Amortization of actuarial loss
   
746
   
812
   
1,492
   
1,623
 
 
Sub-total
   
1,806
   
1,748
   
3,611
   
3,496
 
 
Regulatory adjustment
   
105
   
223
   
210
   
446
 
 
Net postretirement benefit cost
 
$
1,911
 
$
1,971
 
$
3,821
 
$
3,942
 


 
9
 
 


Missouri state law provides for the recovery in rates of SFAS No. 106, “Employers’ Accounting for Postretirement Benefits Other Than Pensions,” accrued costs provided that such costs are funded through an independent, external funding mechanism. Laclede Gas established Voluntary Employees’ Beneficiary Association (VEBA) and Rabbi trusts as its external funding mechanisms. VEBA and Rabbi trusts’ assets consist primarily of money market securities and mutual funds invested in stocks and bonds.
Pursuant to a MoPSC Order, the return on plan assets is based on the market-related value of plan assets implemented prospectively over a four-year period. Gains and losses not yet includible in postretirement benefit cost are amortized only to the extent that such gain or loss exceeds 10% of the greater of the accumulated postretirement benefit obligation or the market-related value of plan assets. Such excess is amortized over the average remaining service life of active participants. Previously, the recovery in rates for the postretirement benefit costs was based on an alternative methodology for amortization of unrecognized gains and losses as ordered by the MoPSC. The Commission ordered that the recovery in rates be based on an annual allowance of $7.6 million, effective August 1, 2007. The difference between this amount and postretirement benefit cost based on the above and that otherwise would be included in the Statements of Income and Comprehensive Income is deferred as a regulatory asset or regulatory liability.


3.
INCOME TAXES

Laclede Group files a consolidated federal and state tax return and allocates income taxes to Laclede Gas and its other subsidiaries as if each entity were a separate taxpayer. Laclede Group and Laclede Gas adopted the provisions of FIN 48, “Accounting for the Uncertainty in Income Taxes,” as of October 1, 2007. FIN 48 clarifies the accounting for uncertainty in income taxes recognized in an enterprise’s financial statements in accordance with FASB Statement No. 109, “Accounting for Income Taxes.” Pursuant to FIN 48, the Utility may recognize the tax benefit from a tax position only if it is at least more likely than not that the tax position will be sustained on examination by the taxing authorities, based on the technical merits of the position.
Upon adoption of FIN 48, Laclede Gas recognized an increase to beginning retained earnings as a cumulative-effect adjustment totaling $0.4 million and reclassified $2.1 million of income tax liabilities from current to non-current liabilities. Total unrecognized tax benefits as of October 1, 2007 were $1.9 million, all of which would favorably impact the effective tax rate, if recognized. The Utility recognizes potential accrued interest and penalties related to its uncertain tax positions as interest expense and other income deductions, respectively. Potential interest and penalties accrued (net of income tax benefit) associated with the Utility’s uncertain tax positions were $0.2 million at October 1, 2007. Unrecognized tax benefits, accrued interest payable, and accrued penalties payable are included in the Other line of the Deferred Credits and Other Liabilities section of the Balance Sheets.
Laclede Group and/or Laclede Gas are subject to U.S. federal income tax as well as income tax of state and city jurisdictions. These companies are no longer subject to examination for fiscal years prior to 2004. The statute of limitations remains open until June 15, 2009 and 2010 for fiscal years 2005 and 2006, respectively. However, during the quarter ended March 31, 2008, Laclede Gas effectively settled an audit with the Internal Revenue Service for those periods. Completion of the audit represents an event requiring the Utility to re-evaluate its uncertain tax positions. As a result, the Utility recognized fiscal years 2005 and 2006 unrecognized tax benefits of $1.0 million, which favorably impacted the effective tax rate, and reversed $0.2 million of accrued interest and penalties (net of income tax benefit). The Utility currently expects to recognize $0.4 million of tax benefits, including the reversal of accrued interest and penalties, in June 2008 due to the expiration of the statute of limitations for fiscal year 2004.
Total FIN 48 unrecognized tax benefits at March 31, 2008 were $1.1 million, all of which would favorably impact the effective tax rate, if recognized. Potential interest and penalties associated with these liabilities were $0.1 million. The Utility does not expect to make any significant tax payment related to any of the above obligations within the next twelve months.

 
10
 
 



4.
OTHER INCOME AND (INCOME DEDUCTIONS) – NET

     
Three Months Ended
 
Six Months Ended
 
     
March 31,
 
March 31,
 
 
(Thousands)
 
2008
 
2007
 
2008
 
2007
 
                             
 
Allowance for funds used during construction
 
$
(16
)
$
(2
)
$
(25
)
$
(16
)
 
Interest income
   
389
   
738
   
1,544
   
2,124
 
 
Other income
   
3
   
93
   
540
   
415
 
 
Other income deductions
   
(899
)
 
(371
)
 
(550
)
 
678
 
 
Other Income and (Income Deductions) – Net
 
$
(523
)
$
458
 
$
1,509
 
$
3,201
 

The decrease in Other Income and (Income Deductions) – Net for the six months ended March 31, 2008, compared with the six months ended March 31, 2007, was primarily due to increased investment losses, lower income associated with carrying costs applied to under-recoveries of gas costs, reduced income associated with changes in the cash surrender value of life insurance policies, and other minor variations. Carrying costs on under-recoveries of gas costs are recovered through the Utility’s Purchased Gas Adjustment (PGA) Clause.


5.
INFORMATION BY OPERATING SEGMENT

The Regulated Gas Distribution segment consists of the regulated operations of Laclede Gas. The Non-Regulated Other segment includes the retail sale of gas appliances. There are no material intersegment revenues.

   
Regulated
 
Non-
 
Adjustments 
     
   
Gas
 
Regulated
 
 &
     
(Thousands)
 
Distribution
 
Other
 
Eliminations
 
Total
 
                           
Three Months Ended
                         
March 31, 2008
                         
Operating revenues
 
$
507,089
 
$
740
 
$
 
$
507,829
 
Net income (loss)
   
25,340
   
(40
)
 
   
25,300
 
Total assets
   
1,454,369
   
1,814
   
   
1,456,183
 
                           
Six Months Ended
                         
March 31, 2008
                         
Operating revenues
 
$
827,981
 
$
1,526
 
$
 
$
829,507
 
Net income (loss)
   
41,097
   
(2
)
 
   
41,095
 
Total assets
   
1,454,369
   
1,814
   
   
1,456,183
 
                           
Three Months Ended
                         
March 31, 2007
                         
Operating revenues
 
$
493,593
 
$
778
 
$
 
$
494,371
 
Net income (loss)
   
20,722
   
(4
)
 
   
20,718
 
Total assets
   
1,370,644
   
1,182
   
   
1,371,826
 
                           
Six Months Ended
                         
March 31, 2007
                         
Operating revenues
 
$
842,081
 
$
1,440
 
$
 
$
843,521
 
Net income
   
36,391
   
2
   
   
36,393
 
Total assets
   
1,370,644
   
1,182
   
   
1,371,826
 


 
11
 
 


6.
COMMITMENTS AND CONTINGENCIES

Laclede Gas owns and operates natural gas distribution, transmission and storage facilities, the operations of which are subject to various environmental laws, regulations and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Laclede Gas’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas may be required to incur additional costs. See Note 12 to the Financial Statements included in Laclede Gas’ Fiscal Year 2007 Form 10-K for information relative to environmental matters generally. There have been no significant changes relative to environmental matters during the six months ended March 31, 2008.
On December 28, 2006, the MoPSC Staff proposed a disallowance of $7.2 million related to Laclede Gas’ recovery of its purchased gas costs applicable to fiscal 2005. On September 14, 2007, the Staff withdrew its pursuit of $5.5 million of the disallowance it had originally proposed. Laclede Gas believes that the remaining $1.7 million of the MoPSC Staff’s proposed disallowance lacks merit and intends to vigorously oppose the adjustment in proceedings before the MoPSC.
On December 31, 2007, the MoPSC Staff filed a memorandum with the Commission proposing a disallowance of $2.8 million related to the Laclede Gas’ recovery of its purchased gas costs applicable to fiscal 2006. Laclede Gas believes that the MoPSC Staff’s position lacks merit and intends to vigorously oppose the adjustment in proceedings before the MoPSC. In addition, the MoPSC’s Staff’s memorandum raised questions regarding whether certain sales and capacity release transactions subject to the Federal Energy Regulatory Commission (FERC)’s oversight were consistent with the FERC’s regulations and policies regarding capacity release. The Utility has commenced an internal review of the questions raised by the MoPSC Staff and has notified the FERC Staff that it has taken this action.
Laclede Gas is involved in other litigation, claims and investigations arising in the normal course of business. While the results of such litigation cannot be predicted with certainty, management, after discussion with counsel, believes that the final outcome will not have a material adverse effect on the financial position or results of operations of the Utility.
Laclede Gas has several operating leases for the rental of vehicles that contain provisions requiring Laclede Gas to guarantee certain amounts related to the residual value of the leased property. These leases have various terms, the longest of which extends through 2014. At March 31, 2008, the maximum guarantees under these leases are $1.7 million. However, the Utility estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At March 31, 2008, the carrying value of the liability recognized for these guarantees was $0.3 million.
Laclede Gas has entered into various contracts, expiring on dates through 2017, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at March 31, 2008 are estimated at approximately $519 million. Additional contracts are generally entered into prior to or during the heating season.
 
 
 
 
 
 
 
 
 
 
 
 

 
12
 
 

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

LACLEDE GAS COMPANY
 
This management’s discussion analyzes the financial condition and results of operations of Laclede Gas Company (Laclede Gas or the Utility). It includes management’s view of factors that affect its business, explanations of past financial results including changes in earnings and costs from the prior year periods, and their effects on overall financial condition and liquidity.
 
Certain matters discussed in this report, excluding historical information, include forward-looking statements. Certain words, such as “may,” “anticipate,” “believe,” “estimate,” “expect,” “intend,” “plan,” “seek,” and similar words and expressions identify forward-looking statements that involve uncertainties and risks. Future developments may not be in accordance with our expectations or beliefs and the effect of future developments may not be those anticipated. Among the factors that may cause results to differ materially from those contemplated in any forward-looking statement are:

weather conditions and catastrophic events, particularly severe weather in the natural gas producing areas of the country;
volatility in gas prices, particularly sudden and sustained spikes in natural gas prices;
the impact of higher natural gas prices on our competitive position in relation to suppliers of alternative heating sources, such as electricity;
changes in gas supply and pipeline availability; particularly those changes that impact supply for and access to our market area;
legislative, regulatory and judicial mandates and decisions, some of which may be retroactive, including those affecting
 
allowed rates of return
 
incentive regulation
 
industry structure
 
purchased gas adjustment provisions
 
rate design structure and implementation
 
franchise renewals
 
environmental or safety matters
 
taxes
 
pension and other postretirement benefit liabilities and funding obligations
 
accounting standards;
the results of litigation;
retention of, ability to attract, ability to collect from and conservation efforts of customers;
capital and energy commodity market conditions, including the ability to obtain funds for necessary capital expenditures and general operations and the terms and conditions imposed for obtaining sufficient gas supply;
discovery of material weakness in internal controls; and
employee workforce issues.
 
Readers are urged to consider the risks, uncertainties and other factors that could affect our business as described in this report. All forward-looking statements made in this report rely upon the safe harbor protections provided under the Private Securities Litigation Reform Act of 1995. We do not, by including this statement, assume any obligation to review or revise any particular forward-looking statement in light of future events.
 
The Management’s Discussion and Analysis of Financial Condition and Results of Operations should be read in conjunction with the Utility’s Financial Statements and the Notes thereto.
 
 
 
 
 
 

 
13
 
 


LACLEDE GAS COMPANY

RESULTS OF OPERATIONS

Laclede Gas is regulated by the Missouri Public Service Commission (MoPSC or Commission) and serves the City of St. Louis and parts of ten other counties in eastern Missouri. Laclede Gas delivers natural gas to retail customers at rates, and in accordance with tariffs, authorized by the MoPSC. The Utility’s earnings are primarily generated by the sale of heating energy. The Utility’s innovative weather mitigation rate design lessens the impact of weather volatility on Laclede Gas customers during cold winters and stabilizes the Utility’s earnings by recovering fixed costs more evenly during the heating season. Due to the seasonal nature of the business of Laclede Gas, earnings are typically concentrated in the November through April period, which generally corresponds with the heating season.

Mitigating the impact of weather fluctuations on Laclede Gas customers while improving the ability to recover its authorized distribution costs and return continues to be a fundamental component of Laclede Gas’ strategy. The Utility’s distribution costs are the essential, primarily fixed expenditures it must incur to operate and maintain a more than 16,000 mile natural gas distribution system and related storage facilities. In addition, Laclede Gas is working to continually improve its ability to provide reliable natural gas service at a reasonable cost, while maintaining and building a secure and dependable infrastructure. The settlement of the Utility’s 2007 rate case resulted in enhancements to the Utility’s weather mitigation rate design that better ensure the recovery of its fixed costs and margins despite variations in sales volumes due to the impacts of weather and other factors that affect customer usage. The Utility’s income from off-system sales remains subject to fluctuations in market conditions. In conjunction with the settlement of the 2005 rate case, effective October 1, 2005, the Utility retained all pre-tax income from off-system sales and capacity release revenues up to $12 million annually. Pre-tax amounts in excess of $12 million were shared with customers, with the Utility retaining 50% of amounts exceeding that threshold. The Stipulation & Agreement approved by the MoPSC in the Utility’s 2007 rate case increases the portion of pre-tax income from off-system sales and capacity release revenues that is shared with customers. Effective October 1, 2007, the Utility is allowed to retain 15% to 25% of the first $6 million in annual income earned (depending on the level of income earned) and 30% of income exceeding $6 million annually. Some of the factors impacting the level of off-system sales include the availability and cost of the Utility’s natural gas supply, the weather in its service area, and the weather in other markets. When Laclede Gas’ service area experiences warmer-than-normal weather while other markets experience colder weather or supply constraints, some of the Utility’s natural gas supply is available for off-system sales and there may be a demand for such supply in other markets.

Laclede Gas continues to work actively to reduce the impact of higher costs associated with wholesale natural gas prices by strategically structuring its natural gas supply portfolio and through the use of financial instruments. Nevertheless, the cost of purchased gas remains high, relative to historical levels. The Utility’s Purchased Gas Adjustment (PGA) Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies, including costs, cost reductions, and related carrying costs associated with the use of financial instruments to hedge the purchase price of natural gas, as well as gas inventory carrying costs. The Utility believes it will continue to be able to obtain sufficient gas supply. The generally higher price levels may continue to affect sales volumes (due to the conservation efforts of customers) and cash flows (associated with the timing of collection of gas costs and related accounts receivable from customers).

Quarter Ended March 31, 2008

Earnings

Laclede Gas’ net income for the quarter ended March 31, 2008 was $25.3 million, compared with net income of $20.7 million for the same quarter last year. The increase in net income was primarily due to the following factors, quantified on a pre-tax basis:

the benefit of the general rate increase, effective August 1, 2007, totaling $11.5 million; and,
the recognition of previously unrecognized tax benefits and the reversal of related expenses, totaling $1.1 million.



 
14
 
 


These factors were partially offset by:

lower income from off-system sales and capacity release, totaling $4.2 million, primarily due to a reduction in the Utility’s share of such income (pursuant to the 2007 rate case); and,
an increase in the provision for uncollectible accounts, totaling $1.8 million.

Utility Operating Revenues and Operating Expenses

Laclede Gas passes on to Utility customers (subject to prudence review) increases and decreases in the wholesale cost of natural gas in accordance with its PGA Clause. The volatility of the wholesale natural gas market results in fluctuations from period to period in the recorded levels of, among other items, revenues and natural gas cost expense. Nevertheless, increases and decreases in the cost of gas associated with system gas sales volumes have no direct effect on net revenues and net income.

Utility operating revenues for the quarter ended March 31, 2008 were $507.1 million, or $13.5 million more than the same quarter last year. Temperatures experienced in the Utility’s service area during the quarter were 10.1% colder than the same quarter last year and 1.0% colder than normal. Total system therms sold and transported were 0.45 billion for the quarter ended March 31, 2008 compared with 0.40 billion for the same quarter last year. Total off-system therms sold and transported were 0.06 billion for the quarter ended March 31, 2008 compared with 0.09 billion for the same quarter last year. The increase in utility operating revenues was primarily attributable to the following factors:

   
Millions
 
Higher system sales volumes, primarily due to colder weather, and other variations
 
$
42.6
 
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
   
(26.6
)
Lower off-system sales volumes
   
(24.0
)
General rate increase, effective August 1, 2007
   
11.5
 
Higher prices charged for off-system sales
   
10.6
 
Lower Infrastructure System Replacement Surcharge (ISRS) revenues
   
(0.6
)
Total Variation
 
$
13.5
 

Utility operating expenses for the quarter ended March 31, 2008 increased $7.0 million from the same quarter last year. Natural and propane gas expense increased $4.0 million, or 1.1%, from last year’s level, primarily attributable to higher system volumes purchased for sendout, partially offset by lower rates charged by our suppliers and lower off-system gas expense. Other operation and maintenance expenses increased $1.9 million, or 4.5%, primarily due to a higher provision for uncollectible accounts, the effect of a gain on the disposal of assets recorded last year, and higher wage rates. These factors were partially offset by decreased maintenance and distribution charges. Taxes, other than income, increased $0.9 million, or 3.2%, primarily due to higher gross receipts taxes (attributable to the increased revenues).

Other Income and (Income Deductions) - Net

Other income and income deductions – net decreased $1.0 million due to increased investment losses and lower income associated with carrying costs applied to under-recoveries of gas costs, and other minor variations. Such carrying costs are recovered through the Utility’s PGA Clause.

Interest Charges

The $1.0 million decrease in interest charges was primarily due to a reduction in interest on long-term debt resulting from the November 2007 maturity of $40 million principal amount of 7 1/2% First Mortgage Bonds.

Income Taxes

The $1.9 million increase in income taxes was primarily due to higher pre-tax income, partially offset by the recognition of previously unrecognized tax benefits recorded pursuant to Financial Accounting Standards Board Interpretation No. 48 (FIN 48), “Accounting for Uncertainty in Income Taxes.”


 
15
 
 


Six Months Ended March 31, 2008

Laclede Gas’ net income for the six months ended March 31, 2008 was $41.1 million, compared with net income of $36.4 million for the same period last year. The benefit of the general rate increase effective August 1, 2007, totaling $21.6 million, was partially offset by the following factors, quantified on a pre-tax basis:

lower income from off-system sales and capacity release, totaling $7.5 million, primarily due to a reduction in the Utility’s share of such income (pursuant to the 2007 rate case);
the net effect of lower system gas sales margins, primarily due to an unusually late start to the heating season, and other variations totaling $2.7 million;
an increase in the provision for uncollectible accounts, totaling $2.3 million; and,
increases in operation and maintenance expenses totaling $1.8 million.

Utility Operating Revenues and Operating Expenses

Utility operating revenues for the six months ended March 31, 2008 were $828.0 million, or $14.1 million less than the same period last year. Temperatures experienced in the Utility’s service area during the six months ended March 31, 2008 were 5.9% colder than the same period last year, but 2.9% warmer than normal. Total system therms sold and transported were 0.72 billion for the six months ended March 31, 2008 compared with 0.68 billion for the same period last year. Total off-system therms sold and transported were 0.11 billion for the six months ended March 31, 2008 compared with 0.15 billion for the same period last year. Increases and decreases in the cost of gas associated with system gas sales volumes have no direct effect on net revenues and net income. The decrease in utility operating revenues was primarily attributable to the following factors:

   
Millions
 
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
 
$
(43.2
)
Lower off-system sales volumes
   
(33.3
)
Higher system sales volumes, primarily due to colder weather, and other variations
   
30.2
 
General rate increase, effective August 1, 2007
   
21.6
 
Higher prices charged for off-system sales
   
11.7
 
Lower ISRS revenues
   
(1.1
)
Total Variation
 
$
(14.1
)

Utility operating expenses for the six months ended March 31, 2008 decreased $21.4 million from the same period last year. Natural and propane gas expense decreased $24.7 million, or 4.0%, from last year’s level, primarily attributable to lower rates charged by our suppliers and lower off-system gas expense, partially offset by increased system volumes purchased for sendout. Other operation and maintenance expenses increased $4.1 million, or 5.0%, primarily due to a higher provision for uncollectible accounts, higher injuries and damages expense, the effect of a gain on the disposal of assets recorded last year, increased pension costs, and higher wage rates. These factors were partially offset by lower group insurance charges and other variations. Depreciation and amortization expense increased $0.4 million, or 2.4%, primarily due to additional depreciable property. Taxes, other than income, decreased $1.2 million, or 2.5%, primarily due to decreased gross receipts taxes and lower property taxes.

Other Income and (Income Deductions) - Net

Other income and income deductions – net decreased $1.7 million due to increased investment losses and lower income associated with carrying costs applied to under-recoveries of gas costs, and other minor variations. Carrying costs on under-recoveries of gas costs are recovered through the Utility’s PGA Clause.

Interest Charges

The $0.9 million decrease in interest charges was primarily due to a reduction in interest on long-term debt resulting from the November 2007 maturity of $40 million principal amount of 7 1/2% First Mortgage Bonds.

Income Taxes

The $1.8 million increase in income taxes was primarily due to higher pre-tax income, partially offset by the recognition of previously unrecognized tax benefits recorded pursuant to FIN 48.

 
16
 
 


REGULATORY MATTERS

During fiscal 2006, the MoPSC approved permanent modifications to the Cold Weather Rule affecting the disconnection and reconnection practices of utilities during the winter heating season. Those modifications included provisions to allow the Utility to obtain accounting authorizations and defer for future recovery certain costs incurred with the modifications. During fiscal 2007, the Utility deferred for future recovery $2.7 million of costs associated with the fiscal 2007 heating season. On October 31, 2007, the Utility filed for determination and subsequent recovery of the deferred amount. On November 16, 2007, the MoPSC directed the MoPSC Staff and the Missouri Office of Public Counsel to submit their positions regarding the Utility’s filing by February 28, 2008. On February 28, 2008, the Utility and MoPSC Staff filed a Non-unanimous Stipulation & Agreement in which these parties agreed to a recovery of $2.5 million of costs. The Non-unanimous Stipulation & Agreement was opposed by the Office of the Public Counsel, and a hearing in this matter was held before the Commission on March 31, 2008. On April 17, 2008, the Commission issued its Report and Order in which it determined that the $2.5 million of costs recommended by the Utility and MoPSC Staff was reasonable and would be approved. Consistent with the approved amount, the Utility recorded a reduction in its deferral totaling $0.2 million during the quarter ended March 31, 2008.

On November 9, 2007, the Utility made an ISRS filing with the Commission designed to increase revenues by $1.6 million annually. On January 15, 2008, the Commission approved implementation of the surcharge to be effective January 18, 2008. On April 25, 2008, the Utility made an ISRS filing with the Commission designed to increase revenues by $1.9 million annually, pending approval by the Commission.

On December 28, 2006, the MoPSC Staff proposed a disallowance of $7.2 million related to Laclede Gas’ recovery of its purchased gas costs applicable to fiscal 2005. On September 14, 2007, the Staff withdrew its pursuit of $5.5 million of the disallowance it had originally proposed. Laclede Gas believes that the remaining $1.7 million of the MoPSC Staff’s proposed disallowance lacks merit and intends to vigorously oppose the adjustment in proceedings before the MoPSC.

On December 31, 2007, the MoPSC Staff filed a memorandum with the Commission proposing a disallowance of $2.8 million related to the Laclede Gas’ recovery of its purchased gas costs applicable to fiscal 2006. Laclede Gas believes that the MoPSC Staff’s position lacks merit and intends to vigorously oppose the adjustment in proceedings before the MoPSC. In addition, the MoPSC’s Staff’s memorandum raised questions regarding whether certain sales and capacity release transactions subject to the Federal Energy Regulatory Commission (FERC)’s oversight were consistent with the FERC’s regulations and policies regarding capacity release. The Utility has commenced an internal review of the questions raised by the MoPSC Staff and has notified the FERC Staff that it has taken this action.


CRITICAL ACCOUNTING POLICIES

Our discussion and analysis of our financial condition, results of operations, liquidity, and capital resources is based upon our financial statements, which have been prepared in accordance with accounting principles generally accepted in the United States of America. Generally accepted accounting principles require that we make estimates and judgments that affect the reported amounts of assets, liabilities, revenues and expenses, and related disclosure of contingent assets and liabilities. We evaluate our estimates on an ongoing basis. We base our estimates on historical experience and on various other assumptions that we believe are reasonable under the circumstances, the results of which form the basis for making judgments about the carrying values of assets and liabilities that are not readily apparent from other sources. Actual results may differ from these estimates. We believe the following represent the more significant items requiring the use of judgment and estimates in preparing our financial statements:

 
Allowances for doubtful accounts – Estimates of the collectibility of trade accounts receivable are based on historical trends, age of receivables, economic conditions, credit risk of specific customers, and other factors. The Utility’s provision for uncollectible accounts is dependent on the regulatory treatment provided for such costs. As approved by the MoPSC, the Utility is allowed to defer for future recovery certain costs associated with amendments to the Cold Weather Rule.
   
 
Employee benefits and postretirement obligations – Pension and postretirement obligations are calculated by actuarial consultants that utilize several statistical factors and other assumptions related to future events, such as discount rates, returns on plan assets, compensation increases, and mortality rates. For the Utility, the amount of expense recognized and the amounts reflected in other comprehensive income are dependent upon the regulatory treatment provided for such costs, as discussed further below. Certain liabilities related to group medical benefits and workers’ compensation claims, portions of which are self-insured and/or contain “stop-loss” coverage with third-party insurers to limit exposure, are established based on historical trends.


 
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Laclede Gas accounts for its regulated operations in accordance with Statement of Financial Accounting Standards (SFAS) No. 71, “Accounting for the Effects of Certain Types of Regulation.” This Statement sets forth the application of accounting principles generally accepted in the United States of America for those companies whose rates are established by or are subject to approval by an independent third-party regulator. The provisions of SFAS No. 71 require, among other things, that financial statements of a regulated enterprise reflect the actions of regulators, where appropriate. These actions may result in the recognition of revenues and expenses in time periods that are different than non-regulated enterprises. When this occurs, costs are deferred as assets in the balance sheet (regulatory assets) and recorded as expenses when those amounts are reflected in rates. Also, regulators can impose liabilities upon a regulated company for amounts previously collected from customers and for recovery of costs that are expected to be incurred in the future (regulatory liabilities). Management believes that the current regulatory environment supports the continued use of SFAS No. 71 and that all regulatory assets and regulatory liabilities are recoverable or refundable through the regulatory process. Management believes the following represent the more significant items recorded through the application of SFAS No. 71:

 
The Utility’s PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review, the cost of purchased gas supplies, including the costs, cost reductions, and related carrying costs associated with the Utility’s use of natural gas financial instruments to hedge the purchase price of natural gas. The difference between actual costs incurred and costs recovered through the application of the PGA are recorded as regulatory assets and regulatory liabilities that are recovered or refunded in a subsequent period. The PGA Clause also authorizes the Utility to recover costs it incurs to finance its investment in gas supplies that are purchased during the storage injection season for sale during the heating season. The PGA Clause also permits the application of carrying costs to all over- or under-recoveries of gas costs, including costs and cost reductions associated with the use of financial instruments. Effective October 1, 2007, the PGA Clause also provides for a portion of income from off-system sales and capacity release revenues to be flowed through to customers.
   
 
Laclede Gas records deferred tax liabilities and assets measured by enacted tax rates for the net tax effect of all temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes, and the amounts used for income tax purposes. Changes in enacted tax rates, if any, and certain property basis differences will be reflected by entries to regulatory asset or liability accounts. Pursuant to the direction of the MoPSC, Laclede Gas’ provision for income tax expense for financial reporting purposes reflects an open-ended method of tax depreciation. Laclede Gas’ provision for income tax expense also records the income tax effect associated with the difference between overheads capitalized to construction for financial reporting purposes and those recognized for tax purposes without recording an offsetting deferred income tax expense. These two methods are consistent with the regulatory treatment prescribed by the MoPSC.
   
 
Asset retirement obligations are recorded in accordance with SFAS No. 143, “Accounting for Asset Retirement Obligations” and FIN 47, “Accounting for Conditional Asset Retirement Obligations.” Asset retirement obligations are calculated using various assumptions related to the timing, method of settlement, inflation, and profit margins that third parties would demand to settle the future obligations. These assumptions require the use of judgment and estimates and may change in future periods as circumstances dictate. As authorized by the MoPSC, Laclede Gas accrues future removal costs associated with its property, plant and equipment through its depreciation rates, even if a legal obligation does not exist as defined by SFAS No. 143 and FIN 47. The difference between removal costs recognized in depreciation rates and the accretion expense and depreciation expense recognizable under SFAS No. 143 and FIN 47 is a timing difference between the recovery of these costs in rates and their recognition for financial reporting purposes. Accordingly, consistent with SFAS No. 71, these differences are deferred as regulatory liabilities.
   
 
The amount of net periodic pension and other postretirement benefit cost recognized in the financial statements related to the Utility’s qualified pension plans and other postretirement benefit plans is based upon allowances, as approved by the MoPSC, which have been established in the rate-making process for the recovery of these costs from customers. The differences between these amounts and actual pension and other postretirement benefit costs incurred for financial reporting purposes are deferred as regulatory assets or regulatory liabilities. SFAS No. 158, “Employers’ Accounting for Defined Benefit Pension and Other Postretirement Plans,” requires that changes that affect the funded status of pension and other postretirement benefit plans, but that are not yet required to be recognized as components of pension and other postretirement benefit cost, be reflected in other comprehensive income. For the Utility’s qualified pension plans and other postretirement benefit plans, amounts that would otherwise be reflected in other comprehensive income are deferred with entries to regulatory assets or regulatory liabilities.


 
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For further discussion of significant accounting policies, see Note 1 to the Financial Statements included in Exhibit 99.1 of the Laclede Group’s Form 10-K for the fiscal year ended September 30, 2007.


ACCOUNTING PRONOUNCEMENTS

Laclede Gas has evaluated or is in the process of evaluating the impact that recently issued accounting standards will have on the Utility’s financial position or results of operations upon adoption. For disclosures related to the adoption of new accounting standards, see the New Accounting Standards section of Note 1 to the Financial Statements.


FINANCIAL CONDITION

CREDIT RATINGS

As of March 31, 2008, credit ratings for outstanding securities for Laclede Gas issues were as follows:

Type of Facility
S&P
Moody’s
Fitch
Laclede Gas First Mortgage Bonds
A
A3
A+
Laclede Gas Commercial Paper
A-1
P-2
 

The Utility has investment grade ratings, and believes that it will have adequate access to the financial markets to meet its capital requirements. These ratings remain subject to review and change by the rating agencies.


CASH FLOWS

Laclede Gas’ short-term borrowing requirements typically peak during colder months when Laclede Gas borrows money to cover the lag between when it purchases its natural gas and when its customers pay for that gas. Changes in the wholesale cost of natural gas, variations in the timing of collections of gas cost under the Utility’s PGA Clause, the seasonality of accounts receivable balances, and the utilization of storage gas inventories cause short-term cash requirements to vary during the year, and can cause significant variations in the Utility’s cash provided by or used in operating activities.

Net cash provided by operating activities for the six months ended March 31, 2008 was $122.6 million, compared with $132.8 million for the same period last year. The variation is primarily attributable to an increase in net cash payments to Laclede Group for the Utility’s allocation of income taxes and variations associated with the timing of the collections of gas cost under the Utility’s PGA Clause. These factors were partially offset by a reduction in net cash payments associated with the Utility’s use of natural gas financial instruments.

Net cash used in investing activities for the six months ended March 31, 2008 and 2007 was $26.2 million. Cash used in investing activities primarily reflected capital expenditures in both periods.

Net cash used in financing activities was $94.0 million for the six months ended March 31, 2008 compared with $103.9 million for the six months ended March 31, 2007. The variation primarily reflects a decrease in net repayments of short-term debt, partially offset by the maturity of long-term debt this year.


LIQUIDITY AND CAPITAL RESOURCES

As indicated above, the Utility’s short-term borrowing requirements typically peak during the colder months. These short-term cash requirements have traditionally been met through the sale of commercial paper supported by lines of credit with banks. Laclede Gas has a line of credit in place of $320 million. During the second quarter, the expiration of this line was extended one year to December 2011 from December 2010. In November 2007, the Utility established a seasonal line of credit of $40 million, which expired in March 2008. The Utility had short-term borrowings aggregating to a maximum of $298.7 million at any one time during the second quarter. Short-term borrowings outstanding at March 31, 2008 were $171.7 million, at a weighted average interest rate of 3.1% per annum. Based on short-term borrowings at March 31, 2008, a change in interest rates of 100 basis points would increase or decrease pre-tax earnings and cash flows by approximately $1.7 million on an annual basis. Portions of such increases or decreases may be offset through the application of PGA carrying costs.

 
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Laclede Gas’ lines of credit include covenants limiting total debt, including short-term debt, to no more than 70% of total capitalization and requiring earnings before interest, taxes, depreciation and amortization (EBITDA) to be at least 2.25 times interest expense. On March 31, 2008, total debt was 56% of total capitalization. For the twelve months ended March 31, 2008, EBITDA was 3.67 times interest expense.

Laclede Gas has on file with the Securities and Exchange Commission an effective shelf registration on Form S-3 for issuance of $350 million of securities. The full amount of this shelf registration remains available to Laclede Gas at this time. The Utility has authority from the MoPSC to issue up to $500 million in first mortgage bonds, unsecured debt, and equity securities. In February 2008, pursuant to this authority, the Utility sold 28 shares of its common stock to Laclede Group for $1.0 million, leaving $494.2 million remaining under this authorization as of the date of this filing. The amount, timing and type of additional financing to be issued will depend on cash requirements and market conditions.

On November 1, 2007, Laclede Gas paid at maturity $40 million principal amount of 7 1/2% First Mortgage Bonds. This maturity was funded through short-term borrowings. At March 31, 2008, Laclede Gas had fixed-rate long-term debt totaling $310 million. While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if Laclede Gas were to reacquire any of these issues in the open market prior to maturity.

Laclede Gas has several operating leases for the rental of vehicles that contain provisions requiring Laclede Gas to guarantee certain amounts related to the residual value of the leased property. These leases have various terms, the longest of which extends through 2014. At March 31, 2008, the maximum guarantees under these leases are $1.7 million. However, the Utility estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At March 31, 2008, the carrying value of the liability recognized for these guarantees was $0.3 million.

Utility capital expenditures were $26.4 million for the six months ended March 31, 2008, compared with $26.1 million for the same period last year.

Capitalization at March 31, 2008, excluding current obligations of preferred stock, consisted of 54.7% common stock equity, 0.1% preferred stock, and 45.2% long-term debt.

It is management’s view that Laclede Gas has adequate access to capital markets and will have sufficient capital resources, both internal and external, to meet anticipated capital requirements.

The seasonal nature of Laclede Gas’ sales affects the comparison of certain balance sheet items at March 31, 2008 and at September 30, 2007, such as Accounts Receivable – Net, Gas Stored Underground, Notes Payable, Accounts Payable, Regulatory Assets and Regulatory Liabilities, and Delayed and Advance Customer Billings. The Balance Sheet at March 31, 2007 is presented to facilitate comparison of these items with the corresponding interim period of the preceding fiscal year.


CONTRACTUAL OBLIGATIONS

As of March 31, 2008, Laclede Gas had contractual obligations with payments due as summarized below (in millions):

   
Payments due by period
 
       
Remaining
         
Fiscal Years
 
 
Contractual Obligations
 
Total
 
Fiscal Year
2008
 
Fiscal Years
2009-2010
 
Fiscal Years
2011-2012
 
2013 and
thereafter
 
Principal Payments on Long-Term Debt
 
$
310.0
 
$
 
$
 
$
25.0
 
$
285.0
 
Interest Payments on Long-Term Debt
   
391.0
   
9.8
   
39.0
   
36.6
   
305.6
 
Operating Leases (a)
   
12.0
   
2.6
   
7.4
   
2.0
   
 
Purchase Obligations – Natural Gas (b)
   
519.3
   
153.7
   
164.9
   
129.6
   
71.1
 
Purchase Obligations – Other (c)
   
108.3
   
10.3
   
18.6
   
16.3
   
63.1
 
Total (d)
 
$
1,340.6
 
$
176.4
 
$
229.9
 
$
209.5
 
$
724.8
 


 
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(a)
Operating lease obligations are primarily for office space, vehicles, and power operated equipment. Additional payments will be incurred if renewal options are exercised under the provisions of certain agreements.
(b)
These purchase obligations represent the minimum payments required under existing natural gas transportation and storage contracts and natural gas supply agreements. These amounts reflect fixed obligations as well as obligations to purchase natural gas at future market prices, calculated using March 31, 2008 New York Mercantile Exchange futures prices. Laclede Gas recovers the costs related to its purchases, transportation, and storage of natural gas through the operation of its Purchased Gas Adjustment Clause, subject to prudence review; however, variations in the timing of collections of gas costs from customers affect short-term cash requirements. Additional contractual commitments are generally entered into prior to or during the heating season.
(c)
These purchase obligations reflect miscellaneous agreements for the purchase of materials and the procurement of services necessary for normal operations.
(d)
The categories of Capital Leases and Other Long-Term liabilities have been excluded from the table above because there are no applicable amounts of contractual obligations under these categories. Also, commitments related to pension and postretirement benefit plans have been excluded from the table above. The Utility expects to make contributions to its qualified, trusteed pension plans totaling $0.6 million during the remainder of fiscal year 2008. Laclede Gas anticipates a $0.2 million contribution relative to its non-qualified pension plans during the remainder of fiscal year 2008. With regard to the postretirement benefits, the Utility anticipates it will contribute $4.1 million to the qualified trusts and $0.2 million directly to participants from Laclede Gas’ funds during the remainder of fiscal year 2008. For further discussion of the Utility’s pension and postretirement benefit plans, refer to Note 2, Pension Plans and Other Postretirement Benefits, of the Notes to Financial Statements.


MARKET RISK

Laclede Gas adopted a risk management policy that provides for the purchase of natural gas financial instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. This policy prohibits speculation. Costs and cost reductions, including carrying costs, associated with the Utility’s use of natural gas financial instruments are allowed to be passed on to the Utility’s customers through the operation of its PGA Clause, through which the MoPSC allows the Utility to recover gas supply costs. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these financial instruments. At March 31, 2008, the Utility held 10.6 million MMBtu of futures contracts at an average price of $7.78 per MMBtu. Additionally, approximately 10.4 million MMBtu of other price risk mitigation was in place through the use of option-based strategies. These positions have various expiration dates, the longest of which extends through March 2009.


ENVIRONMENTAL MATTERS

Laclede Gas owns and operates natural gas distribution, transmission and storage facilities, the operations of which are subject to various environmental laws, regulations and interpretations. While environmental issues resulting from such operations arise in the ordinary course of business, such issues have not materially affected the Laclede Gas’ financial position and results of operations. As environmental laws, regulations, and their interpretations change, however, Laclede Gas may be required to incur additional costs. For information relative to environmental matters, see Note 12 to the Financial Statements included in the Utility’s Form 10-K for the fiscal year ended September 30, 2007. There have been no significant changes relative to environmental matters during the six months ended March 31, 2008.


OFF-BALANCE SHEET ARRANGEMENTS

Laclede Gas has no off-balance sheet arrangements.
 

 
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