UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D. C. 20549
 
FORM 10-Q

[ X ]
QUARTERLY REPORT PURSUANT TO SECTION 13 or 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Quarter Ended December 31, 2011
OR
[     ]
TRANSITION REPORT PURSUANT TO SECTION 13 or 15 (d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the Transition Period from ­__________ to __________

Commission File Number 1-16681

THE LACLEDE GROUP, INC. LOGO

THE LACLEDE GROUP, INC.
(Exact name of registrant as specified in its charter)

Missouri
(State of Incorporation)
74-2976504
(I.R.S. Employer Identification number)
 
720 Olive Street
St. Louis, MO  63101
(Address and zip code of principal executive offices)
 
314-342-0500
(Registrant’s telephone number, including area code)

Indicate by check mark if the registrant:

(1) has 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) has been subject to such filing requirements for the past 90 days. Yes [ X ] No [     ]

has submitted electronically and posted on its corporate Web site, if any, every Interactive Data File required to be submitted and posted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrant was required to submit and post such files). Yes [ X ] No [     ]

is a large accelerated filer, an accelerated filer, a non-accelerated filer, or a smaller reporting company. See the definitions of “large accelerated filer,” “accelerated filer,” and “smaller reporting company” in Rule 12b-2 of the Exchange Act.

 
Large accelerated filer
[ X ]
 
Accelerated filer
[     ]
 
Non-accelerated filer
[     ]
 
Smaller reporting company
[     ]

is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes [     ] No [ X ]

As of January 26, 2012, there were 22,486,439 shares of the registrant’s Common Stock, par value $1.00 per share, outstanding.
 


 
 
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2
 


PART I . FINANCIAL INFORMATION
 
The interim financial statements included herein have been prepared by The Laclede Group, Inc. (Laclede Group or 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, 2011.





Item 1 . Financial Statements
THE LACLEDE GROUP, INC .
STATEMENTS OF CONSOLIDATED INCOME
 (UNAUDITED)

   
Three Months Ended
 
   
December 31,
 
(Thousands, Except Per Share Amounts)
 
2011
 
2010
 
               
Operating Revenues:
             
  Regulated Gas Distribution
 
$
250,902
 
$
277,443
 
  Non-Regulated Gas Marketing
   
158,588
   
166,408
 
  Other
   
1,423
   
351
 
        Total Operating Revenues
   
410,913
   
444,202
 
Operating Expenses:
             
  Regulated Gas Distribution
             
    Natural and propane gas
   
146,751
   
173,365
 
    Other operation expenses
   
37,565
   
34,862
 
    Maintenance
   
5,308
   
6,140
 
    Depreciation and amortization
   
10,089
   
9,638
 
    Taxes, other than income taxes
   
14,667
   
15,748
 
        Total Regulated Gas Distribution Operating Expenses
   
214,380
   
239,753
 
  Non-Regulated Gas Marketing
   
152,559
   
163,353
 
  Other
   
869
   
345
 
        Total Operating Expenses
   
367,808
   
403,451
 
Operating Income
   
43,105
   
40,751
 
Other Income and (Income Deductions) – Net
   
1,939
   
1,845
 
Interest Charges:
             
  Interest on long-term debt
   
5,739
   
5,942
 
  Other interest charges
   
575
   
744
 
        Total Interest Charges
   
6,314
   
6,686
 
Income Before Income Taxes
   
38,730
   
35,910
 
Income Tax Expense
   
13,556
   
12,541
 
Net Income
 
$
25,174
 
$
23,369
 
               
Weighted Average Number of Common Shares Outstanding:
             
  Basic
   
22,193
   
22,041
 
  Diluted
   
22,263
   
22,120
 
               
Basic Earnings Per Share of Common Stock
 
$
1.13
 
$
1.05
 
               
Diluted Earnings Per Share of Common Stock
 
$
1.12
 
$
1.05
 
               
Dividends Declared Per Share of Common Stock
 
$
0.415
 
$
0.405
 
               
             



STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME
(UNAUDITED)

   
Three Months Ended
 
   
December 31,
 
(Thousands)
 
2011
 
2010
 
               
Net Income
 
$
25,174
 
$
23,369
 
Other Comprehensive Income (Loss), Before Tax:
             
  Net gains (losses) on cash flow hedging derivative instruments:
             
    Net hedging gain arising during the period
   
3,047
   
214
 
    Reclassification adjustment for gains included in net income
   
(2,830
)
 
(3,090
)
        Net unrealized gains (losses) on cash flow hedging derivative instruments
   
217
   
(2,876
)
   Amortization of actuarial loss included in net periodic pension and
             
     postretirement benefit cost
   
91
   
107
 
Other Comprehensive Income (Loss), Before Tax
   
308
   
(2,769
)
Income Tax Expense (Benefit) Related to Items of Other Comprehensive Income (Loss)
   
119
   
(1,070
)
Other Comprehensive Income (Loss), Net of Tax
   
189
   
(1,699
)
Comprehensive Income
 
$
25,363
 
$
21,670
 
               
             














CONSOLIDATED BALANCE SHEETS
(UNAUDITED)

   
Dec. 31,
     
Sept. 30,
     
Dec. 31,
 
(Thousands)
 
2011
     
2011
     
2010
 
                             
ASSETS
                           
Utility Plant
 
$
1,400,001
     
$
1,386,590
     
$
1,338,568
 
  Less:  Accumulated depreciation and amortization
   
463,148
       
457,907
       
447,582
 
        Net Utility Plant
   
936,853
       
928,683
       
890,986
 
                             
Non-utility property
   
4,449
       
4,588
       
4,538
 
Other investments
   
52,508
       
50,785
       
50,505
 
        Other Property and Investments
   
56,957
       
55,373
       
55,043
 
                             
Current Assets:
                           
  Cash and cash equivalents
   
44,579
       
43,277
       
25,087
 
  Accounts receivable:
                           
    Utility
   
135,758
       
71,090
       
165,171
 
    Non-utility
   
49,902
       
50,894
       
61,951
 
    Other
   
17,554
       
12,572
       
11,055
 
    Allowance for doubtful accounts
   
(5,989
)
     
(10,073
)
     
(6,732
)
  Inventories:
                           
    Natural gas stored underground at LIFO cost
   
113,668
       
115,170
       
109,171
 
    Propane gas at FIFO cost
   
8,964
       
8,961
       
16,881
 
    Materials, supplies, and merchandise at average cost
   
4,855
       
4,229
       
4,255
 
  Natural gas receivable
   
15,327
       
30,689
       
12,320
 
  Derivative instrument assets
   
3,232
       
7,759
       
13,150
 
  Unamortized purchased gas adjustments
   
19,413
       
25,719
       
18,136
 
  Deferred income taxes
   
       
       
1,162
 
  Prepayments and other
   
8,250
       
8,847
       
6,080
 
        Total Current Assets
   
415,513
       
369,134
       
437,687
 
                             
Deferred Charges:
                           
  Regulatory assets
   
458,648
       
423,492
       
453,030
 
  Other
   
6,359
       
6,400
       
7,481
 
        Total Deferred Charges
   
465,007
       
429,892
       
460,511
 
Total Assets
 
$
1,874,330
     
$
1,783,082
     
$
1,844,227
 
                             

 
 

 
 
 
 




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

   
Dec. 31,
     
Sept. 30,
     
Dec. 31,
 
(Thousands, except share amounts)
 
2011
     
2011
     
2010
 
                             
CAPITALIZATION AND LIABILITIES
                           
Capitalization:
                           
  Common stock (70,000,000 shares authorized, 22,478,635
    22,430,734, and  22,376,183 shares issued, respectively)
 
$
22,479
     
$
22,431
     
$
22,376
 
  Paid-in capital
   
163,944
       
163,702
       
158,976
 
  Retained earnings
   
405,158
       
389,298
       
376,055
 
  Accumulated other comprehensive loss
   
(1,911
)
     
(2,100
)
     
(8,836
)
      Total Common Stock Equity
   
589,670
       
573,331
       
548,571
 
  Long-term debt (less current portion) – Laclede Gas
   
339,372
       
364,357
       
364,313
 
      Total Capitalization
   
929,042
       
937,688
       
912,884
 
                             
Current Liabilities:
                           
  Notes payable
   
113,000
       
46,000
       
97,450
 
  Accounts payable
   
94,313
       
96,561
       
125,315
 
  Advance customer billings
   
11,600
       
15,230
       
9,639
 
  Current portion of long-term debt
   
25,000
       
       
 
  Wages and compensation accrued
   
12,529
       
13,650
       
12,406
 
  Dividends payable
   
9,626
       
9,359
       
9,195
 
  Customer deposits
   
10,080
       
10,048
       
11,315
 
  Interest accrued
   
5,519
       
8,812
       
5,756
 
  Taxes accrued
   
11,694
       
11,901
       
17,633
 
  Deferred income taxes
   
7,516
       
8,405
       
 
  Other
   
22,302
       
11,968
       
26,623
 
      Total Current Liabilities
   
323,179
       
231,934
       
315,332
 
                             
Deferred Credits and Other Liabilities:
                           
  Deferred income taxes
   
335,255
       
315,405
       
297,792
 
  Unamortized investment tax credits
   
3,272
       
3,326
       
3,485
 
  Pension and postretirement benefit costs
   
172,791
       
185,701
       
210,642
 
  Asset retirement obligations
   
27,904
       
27,495
       
26,224
 
  Regulatory liabilities
   
51,904
       
50,846
       
47,898
 
  Other
   
30,983
       
30,687
       
29,970
 
      Total Deferred Credits and Other Liabilities
   
622,109
       
613,460
       
616,011
 
Commitments and Contingencies ( Note 11 )
                           
Total Capitalization and Liabilities
 
$
1,874,330
     
$
1,783,082
     
$
1,844,227
 
                             
                           
                             
                             




STATEMENTS OF CONSOLIDATED CASH FLOWS
(UNAUDITED)
 
   
Three Months Ended
 
   
December 31,
 
(Thousands)
 
2011
     
2010
 
                   
Operating Activities:
                 
  Net Income
 
$
25,174
     
$
23,369
 
  Adjustments to reconcile net income to net cash provided by (used in)
      operating activities:
                 
    Depreciation, amortization, and accretion
   
10,239
       
9,766
 
    Deferred income taxes and investment tax credits
   
7,940
       
1,078
 
    Other – net
   
(251
)
     
(387
)
    Changes in assets and liabilities:
                 
      Accounts receivable – net
   
(72,742
)
     
(103,856
)
      Unamortized purchased gas adjustments
   
6,306
       
5,582
 
      Deferred purchased gas costs
   
(26,415
)
     
30,860
 
      Accounts payable
   
(224
)
     
31,159
 
      Advance customer billings
   
(3,630
)
     
(7,170
)
      Taxes accrued
   
(805
)
     
7,125
 
      Natural gas stored underground
   
1,502
       
4,405
 
      Other assets and liabilities
   
2,807
       
3,866
 
          Net cash (used in) provided by operating activities
   
(50,099
)
     
5,797
 
                   
Investing Activities:
                 
  Capital expenditures
   
(18,334
)
     
(15,627
)
  Other investments
   
(280
)
     
1,002
 
          Net cash used in investing activities
   
(18,614
)
     
(14,625
)
                   
Financing Activities:
                 
  Maturity of first mortgage bonds
   
       
(25,000
)
  Issuance (repayment) of short-term debt – net
   
67,000
       
(32,200
)
  Changes in book overdrafts
   
11,842
       
13,310
 
  Issuance of common stock
   
1,253
       
591
 
  Dividends paid
   
(9,035
)
     
(8,766
)
  Employees’ taxes paid associated with restricted shares withheld upon vesting
   
(1,165
)
     
(1,166
)
  Excess tax benefits from stock-based compensation
   
134
       
227
 
  Other
   
(14
)
     
 
          Net cash provided by (used in) financing activities
   
70,015
       
(53,004
)
                   
Net Increase (Decrease) in Cash and Cash Equivalents
   
1,302
       
(61,832
)
Cash and Cash Equivalents at Beginning of Period
   
43,277
       
86,919
 
Cash and Cash Equivalents at End of Period
 
$
44,579
 
 
 
$
25,087
 
                   
 
                 
Supplemental Disclosure of Cash Paid (Refunded) During the Period for:
                 
    Interest
 
$
9,590
     
$
10,288
 
    Income taxes
   
1,161
       
(132
)
                   
                 






THE LACLEDE GROUP, INC.
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
(UNAUDITED)

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

These notes are an integral part of the accompanying unaudited 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 2011 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.
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 December 31, 2011 and 2010, for the Utility, were $38.3 million and $54.6 million, respectively. The amount of accrued unbilled revenue at September 30, 2011 was $11.8 million.
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 December 31, 2011 and 2010 were $10.2 million, and $11.3 million, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.
NEW ACCOUNTING STANDARDS In May 2011, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) No. 2011-04, “Amendments to Achieve Common Fair Value Measurement Disclosure Requirements in U.S. GAAP and IFRSs.” This ASU amends Accounting Standards Codification (ASC) Topic 820, “Fair Value Measurements and Disclosures,” to improve the comparability of fair value measurements presented and disclosed in financial statements prepared in accordance with U.S. generally accepted accounting principles (GAAP) and International Financial Reporting Standards (IFRS). The ASU does not change what items are measured at fair value, but instead makes various changes to the guidance pertaining to how fair value is measured. Additionally, the ASU sets forth additional disclosure requirements, including additional information about Level 3 fair value measurements. Many of the amendments in this ASU are changes to align the wording in U.S. GAAP with IFRS and, as such, are not intended to result in a change in the application of the guidance. The Company is required to adopt the guidance in this ASU on a prospective basis in the second quarter of fiscal year 2012. The Company does not expect the adoption of this ASU to have a material impact on its financial condition or results of operations.
In June 2011, the FASB issued ASU No. 2011-05, “Presentation of Comprehensive Income,” to amend ASC Topic 220, “Comprehensive Income,” by changing certain financial statement presentation requirements. Under the amended guidance, entities may either present a single continuous statement of comprehensive income or, consistent with the Company’s current presentation, provide separate but consecutive statements (a statement of income and a statement of comprehensive income). ASU No. 2011-05 would have required that, regardless of the method chosen, reclassification adjustments from other comprehensive income to net income be presented on the face of the financial statements, displaying the effect on both net income and other comprehensive income. However, in December 2011, the FASB issued ASU No. 2011-12 to defer the effective date of this particular requirement while it reconsiders this provision of the guidance. The amendments in these ASUs do not change the items that are required to be reported in other comprehensive income and, accordingly, will not impact total net income, comprehensive income, or earnings per share.
In December 2011, the FASB issued ASU No. 2011-11, “Disclosures about Offsetting Assets and Liabilities,” to amend ASC Topic 210, “Balance Sheet,” to require additional disclosures about financial instruments and derivative instruments that have been presented on a net basis (offset) in the balance sheet. Additionally, information about financial instruments and derivative instruments that are subject to enforceable master netting arrangements or similar agreements, irrespective of whether they are presented net in the balance sheet, is required to be disclosed. The ASU
 
 
impacts disclosures only and will not require any changes to financial statement presentation. The Company will present the new disclosures retrospectively beginning in the first quarter of fiscal year 2014.
 
2 .
PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

Pension Plans

Laclede Gas has non-contributory, defined benefit, trusteed forms of pension plans covering substantially all employees. Plan assets consist primarily of corporate and U.S. government obligations and equity market exposure achieved through derivative instruments.
Pension costs for the quarters ended December 31, 2011 and 2010 were $4.2 million and $1.6 million, respectively, including amounts charged to construction.
The net periodic pension costs include the following components:

     
Three Months Ended
 
     
December 31,
 
 
(Thousands)
 
2011
 
2010
 
                 
 
Service cost – benefits earned during the period
 
$
2,312
 
$
2,388
 
 
Interest cost on projected benefit obligation
   
4,871
   
4,705
 
 
Expected return on plan assets
   
(4,899
)
 
(4,712
)
 
Amortization of prior service cost
   
148
   
160
 
 
Amortization of actuarial loss
   
2,277
   
2,557
 
 
Sub-total
   
4,709
   
5,098
 
 
Regulatory adjustment
   
(483
)
 
(3,533
)
 
Net pension cost
 
$
4,226
 
$
1,565
 

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 three months ended December 31, 2011 and December 31, 2010.
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 annual allowance of $4.8 million effective August 1, 2007 and $15.5 million effective January 1, 2011. The difference between these amounts and pension expense as calculated pursuant to the above and that otherwise would be included in the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income is deferred as a regulatory asset or regulatory liability.
The funding policy of Laclede Gas is to contribute an amount not less than the minimum required by government funding standards, nor more than the maximum deductible amount for federal income tax purposes. Fiscal year 2012 contributions to the pension plans through December 31, 2011 were $17.6 million to the qualified trusts and approximately $0.1 million to the non-qualified plans. Contributions to the pension plans for the remaining nine months of fiscal year 2012 are anticipated to be at least $15.7 million to the qualified trusts and $6.6 million to the non-qualified plans.

Postretirement Benefits

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 December 31, 2011 and 2010 were $2.4 million and $1.9 million, respectively, including amounts charged to construction.


Net periodic postretirement benefit costs consisted of the following components:

     
Three Months Ended
 
     
December 31,
 
 
(Thousands)
 
2011
 
2010
 
                 
 
Service cost – benefits earned during the period
 
$
2,015
 
$
1,919
 
 
Interest cost on accumulated
             
 
    postretirement benefit obligation
   
1,380
   
1,211
 
 
Expected return on plan assets
   
(991
)
 
(911
)
 
Amortization of transition obligation
   
34
   
34
 
 
Amortization of prior service credit
   
(518
)
 
(582
)
 
Amortization of actuarial loss
   
1,065
   
1,110
 
 
Sub-total
   
2,985
   
2,781
 
 
Regulatory adjustment
   
(604
)
 
(871
)
 
Net postretirement benefit cost
 
$
2,381
 
$
1,910
 

Missouri state law provides for the recovery in rates of costs accrued pursuant to generally accepted accounting principles (GAAP) 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. The recovery in rates for the Utility’s postretirement benefit plans is based on an annual allowance of $7.6 million effective August 1, 2007 and $9.5 million effective January 1, 2011. The difference between these amounts and postretirement benefit cost based on the above and that otherwise would be included in the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income is deferred as a regulatory asset or regulatory liability.
Laclede Gas’ funding policy is to contribute amounts to the trusts equal to the periodic benefit cost calculated pursuant to GAAP as recovered in rates. Fiscal year 2012 contributions to the postretirement plans through December 31, 2011 were approximately $0.1 million paid directly to participants from Laclede Gas’ funds. No contributions were made to the qualified trusts during the three months ended December 31, 2011. Contributions to the postretirement plans for the remaining nine months of fiscal year 2012 are anticipated to be $11.9 million to the qualified trusts and $0.3 million paid directly to participants from Laclede Gas’ funds.


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 3 of the Consolidated Financial Statements included in the Company’s Form 10-K for the fiscal year ended September 30, 2011 for descriptions of these plans.

Restricted Stock Awards

During the three months ended December 31, 2011, the Company granted 101,963 performance-contingent restricted share units to executive officers and key employees at a weighted average grant date fair value of $36.05 per share. This number represents the maximum shares that can be earned pursuant to the terms of the awards. The share units have a performance period ending September 30, 2014. While the participants have no interim voting rights on these share units, dividends accrue during the performance period and are paid to the participants upon vesting, but are subject to forfeiture if the underlying shares units do not vest. The number of share units that will ultimately vest is dependent upon the attainment of certain levels of earnings and other strategic goals, as well as the Company’s level of total shareholder return (TSR) during the performance period relative to a comparator group of companies. This TSR provision is considered a market condition under generally accepted accounting principles.
 
 
 
 
Activity of restricted stock and restricted stock units subject to performance and/or market conditions during the three months ended December 31, 2011 is presented below:

           
Weighted
           
Average
     
Shares/
   
Grant Date
     
Units
   
Fair Value
                   
 
Nonvested at September 30, 2011
 
259,075
     
$
34.29
 
                   
 
Granted (maximum shares that can be earned)
 
101,963
     
$
36.05
 
 
Vested
 
(48,429
)
   
$
48.70
 
 
Forfeited
 
(35,071
)
   
$
45.07
 
                   
 
Nonvested at December 31, 2011
 
277,538
     
$
31.06
 

During the three months ended December 31, 2011, the Company granted 30,075 shares of time-vested restricted stock to executive officers and key employees at a weighted average grant date fair value of $39.72 per share. These shares were awarded on December 1, 2011 and vest December 1, 2014. In the interim, participants receive full voting rights and dividends, which are not subject to forfeiture.
Time-vested restricted stock and time-vested restricted stock unit activity for the three months ended December 31, 2011 is presented below:

           
Weighted
           
Average
     
Shares/
   
Grant Date
     
Units
   
Fair Value
                   
 
Nonvested at September 30, 2011
 
143,350
     
$
37.00
 
                   
 
Granted
 
30,075
     
$
39.72
 
 
Vested
 
(39,700
)
   
$
42.43
 
 
Forfeited
 
     
$
 
                   
 
Nonvested at December 31, 2011
 
133,725
     
$
36.00
 

During the three months ended December 31, 2011, 88,129 shares of restricted stock and stock units (performance-contingent and time-vested), awarded on February 14, 2008 and November 5, 2008, vested. The Company withheld 29,157 of the vested shares at a weighted average price of $39.96 per share pursuant to elections by employees to satisfy tax withholding obligations.



Stock Option Awards

Stock option activity for the three months ended December 31, 2011 is presented below:

                 
Weighted
       
                 
Average
       
           
Weighted
   
Remaining
   
Aggregate
 
           
Average
   
Contractual
   
Intrinsic
 
     
Stock
   
Exercise
   
Term
   
Value
 
     
Options
   
Price
   
(Years)
   
($000)
 
                               
 
Outstanding at September 30, 2011
 
305,875
   
$
30.72
               
                               
 
Granted
 
   
$
               
 
Exercised
 
(29,000
)
 
$
29.65
               
 
Forfeited
 
   
$
               
 
Expired
 
   
$
               
                               
 
Outstanding at December 31, 2011
 
276,875
   
$
30.84
   
3.1
   
$
2,667
 
                               
 
Fully Vested and Expected to Vest
  at December 31, 2011
 
276,875
   
$
30.84
   
3.1
   
$
2,667
 
                               
 
Exercisable at December 31, 2011
 
276,875
   
$
30.84
   
3.1
   
$
2,667
 

The closing price of the Company’s common stock was $40.47 at December 31, 2011.

Equity Compensation Costs

The amounts of compensation cost recognized for share-based compensation arrangements for the three months ended December 31, 2011 and 2010 are presented below:

     
Three Months Ended
   
     
December 31,
   
 
(Thousands)
   
2011
   
2010
   
                   
 
Total equity compensation cost
 
$
667
 
$
718
   
 
Compensation cost capitalized
   
(138
)
 
(154
)
 
 
Compensation cost recognized in net income
   
529
   
564
   
 
Income tax benefit recognized in net income
   
(204
)
 
(218
)
 
 
Compensation cost recognized in net income, net of income tax
 
$
325
 
$
346
   

As of December 31, 2011, there was $6.5 million of total unrecognized compensation cost related to nonvested share-based compensation arrangements. That cost is expected to be recognized over a weighted average period of 2.4 years.




EARNINGS PER COMMON SHARE


     
Three Months Ended
 
     
December 31,
 
 
(Thousands, Except Per Share Amounts)
   
2011
   
2010
 
                 
 
Basic EPS:
             
 
Net Income
 
$
25,174
 
$
23,369
 
 
  Less: Income allocated to participating securities
   
155
   
201
 
 
Net Income Available to Common Shareholders
 
$
25,019
 
$
23,168
 
                 
 
Weighted Average Shares Outstanding
   
22,193
   
22,041
 
 
Earnings Per Share of Common Stock
 
$
1.13
 
$
1.05
 
                 
 
Diluted EPS:
             
 
Net Income
 
$
25,174
 
$
23,369
 
 
  Less: Income allocated to participating securities
   
155
   
201
 
 
Net Income Available to Common Shareholders
 
$
25,019
 
$
23,168
 
                 
 
Weighted Average Shares Outstanding
   
22,193
   
22,041
 
 
Dilutive Effect of Stock Options
             
 
    and Restricted Stock
   
70
   
79
 
 
Weighted Average Diluted Shares
   
22,263
   
22,120
 
                 
 
Earnings Per Share of Common Stock
 
$
1.12
 
$
1.05
 
                 
 
Outstanding Shares Excluded from the
             
 
Calculation of Diluted EPS Attributable to:
             
 
Restricted stock and stock units subject to
  performance and/or market conditions
   
278
   
193
 




5 .
FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts and estimated fair values of financial instruments are as follows:

 
(Thousands)
 
Carrying
Amount
 
Fair
Value
 
 
As of December 31, 2011
             
 
Cash and cash equivalents
 
$
44,579
 
$
44,579
 
 
Marketable securities
   
15,916
   
15,916
 
 
Derivative instrument assets
   
3,630
   
3,630
 
 
Derivative instrument liabilities
   
48
   
48
 
 
Short-term debt
   
113,000
   
113,000
 
 
Long-term debt, including current portion
   
364,372
   
449,968
 
                 
 
As of September 30, 2011
             
 
Cash and cash equivalents
 
$
43,277
 
$
43,277
 
 
Marketable securities
   
14,833
   
14,833
 
 
Derivative instrument assets
   
8,988
   
8,988
 
 
Derivative instrument liabilities
   
54
   
54
 
 
Short-term debt
   
46,000
   
46,000
 
 
Long-term debt
   
364,357
   
443,739
 
                 
 
As of December 31, 2010
             
 
Cash and cash equivalents
 
$
25,087
 
$
25,087
 
 
Marketable securities
   
13,652
   
13,652
 
 
Derivative instrument assets
   
15,415
   
15,415
 
 
Derivative instrument liabilities
   
35
   
35
 
 
Short-term debt
   
97,450
   
97,450
 
 
Long-term debt
   
364,313
   
393,705
 

The carrying amounts for cash and cash equivalents and short-term debt approximate fair value due to the short maturity of these instruments. The fair values of long-term debt are estimated based on market prices for similar issues. The fair values of marketable securities, derivative instrument assets, and derivative instrument liabilities are valued as described in Note 6 , Fair Value Measurements.




6 .
FAIR VALUE MEASUREMENTS

The following table categorizes the assets and liabilities in the Consolidated Balance Sheets that are accounted for at fair value on a recurring basis in periods subsequent to initial recognition.

 
(Thousands)
   
Quoted
Prices in
Active
Markets
(Level 1)
   
Significant
Observable
Inputs
(Level 2)
   
Significant
Unobservable
Inputs
(Level 3)
   
Effects of Netting and Cash Margin Receivables
/Payables
   
Total
 
 
As of December 31, 2011
                               
 
Assets
                               
 
  U. S. Stock/Bond Mutual Funds
 
$
15,916
 
$
 
$
 
$
 
$
15,916
 
 
  NYMEX/ICE natural gas contracts
   
1,957
   
1,724
   
   
(2,180
)
 
1,501
 
 
  NYMEX gasoline and heating
                               
 
    oil contracts
   
31
   
   
   
(31
)
 
 
 
  Natural gas commodity contracts
   
   
2,111
   
117
   
(99
)
 
2,129
 
 
        Total
 
$
17,904
 
$
3,835
 
$
117
 
$
(2,310
)
$
19,546
 
                                   
 
Liabilities
                               
 
  NYMEX/ICE natural gas contracts
 
$
27,122
 
$
1,400
 
$
 
$
(28,522
)
$
 
 
  Natural gas commodity contracts
   
   
67
   
80
   
(99
)
 
48
 
 
        Total
 
$
27,122
 
$
1,467
 
$
80
 
$
(28,621
)
$
48
 
                                   
 
As of September 30, 2011
                               
 
Assets
                               
 
  U. S. Stock/Bond Mutual Funds
 
$
14,833
 
$
 
$
 
$
 
$
14,833
 
 
  NYMEX/ICE natural gas contracts
   
4,856
   
   
   
1,975
   
6,831
 
 
  NYMEX gasoline and heating
                               
 
    oil contracts
   
19
   
   
   
162
   
181
 
 
  Natural gas commodity contracts
   
   
2,018
   
66
   
(108
)
 
1,976
 
 
        Total
 
$
19,708
 
$
2,018
 
$
66
 
$
2,029
 
$
23,821
 
                                   
 
Liabilities
                               
 
  NYMEX/ICE natural gas contracts
 
$
20,928
 
$
 
$
 
$
(20,928
)
$
 
 
  NYMEX gasoline and heating
                               
 
    oil contracts
   
124
   
   
   
(124
)
 
 
 
  Natural gas commodity contracts
   
   
109
   
53
   
(108
)
 
54
 
 
        Total
 
$
21,052
 
$
109
 
$
53
 
$
(21,160
)
$
54
 
                                   




 
(Thousands)
   
Quoted
Prices in
Active
Markets
(Level 1)
   
Significant
Observable
Inputs
(Level 2)
   
Significant
Unobservable
Inputs
(Level 3)
   
Effects of Netting and Cash Margin Receivables
/Payables
   
Total
 
                                   
 
As of December 31, 2010
                               
 
Assets
                               
 
  U. S. Stock/Bond Mutual Funds
 
$
13,652
 
$
 
$
 
$
 
$
13,652
 
 
  NYMEX/ICE natural gas contracts
   
3,506
   
   
   
11,201
   
14,707
 
 
  NYMEX gasoline and heating
                               
 
    oil contracts
   
182
   
   
   
315
   
497
 
 
  Natural gas commodity contracts
   
   
125
   
140
   
(54
)
 
211
 
 
        Total
 
$
17,340
 
$
125
 
$
140
 
$
11,462
 
$
29,067
 
                                   
 
Liabilities
                               
 
  NYMEX/ICE natural gas contracts
 
$
35,753
 
$
 
$
 
$
(35,753
)
$
 
 
  Natural gas commodity contracts
   
   
25
   
64
   
(54
)
 
35
 
 
        Total
 
$
35,753
 
$
25
 
$
64
 
$
(35,807
)
$
35
 

The mutual funds included in Level 1 are valued based on exchange-quoted market prices of identical securities. Derivative instruments included in Level 1 are valued using quoted market prices on the New York Mercantile Exchange (NYMEX). Derivative instruments classified in Level 2 include physical commodity derivatives that are valued using broker or dealer quotation services whose prices are derived principally from, or are corroborated by, observable market inputs. Also included in Level 2 are certain derivative instruments that have values that are similar to, and correlate with, quoted prices for exchange-traded instruments in active markets. Derivative instruments included in Level 3 are valued using generally unobservable inputs that are based upon the best information available and reflect management’s assumptions about how market participants would price the asset or liability. The Company’s policy is to recognize transfers between the levels of the fair value hierarchy, if any, as of the beginning of the interim reporting period in which circumstances change or events occur to cause the transfer. The following is a reconciliation of the Level 3 beginning and ending net derivative balances:

     
Three Months Ended
 
     
December 31,
 
 
(Thousands)
 
2011
 
2010
 
                 
 
Beginning of period
 
$
13
 
$
23
 
 
Settlements
   
34
   
29
 
 
Net gains (losses) related to derivatives still held
  at end of period
   
(10
)
 
24
 
 
End of period
 
$
37
 
$
76
 

The mutual funds are included in the Other investments line of the Consolidated Balance Sheets. Derivative assets and liabilities, including receivables and payables associated with cash margin requirements, are presented net in the Consolidated Balance Sheets when a legally enforceable netting agreement exists between the Company and the counterparty to a derivative contract. For additional information on derivative instruments, see Note 7 , Derivative Instruments and Hedging Activities.





7 .
DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

Laclede Gas has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing price risk associated with purchasing natural gas on behalf of its customers. This policy prohibits speculation and permits the Utility to hedge up to 70% of its normal volumes purchased for up to a 36-month period. Costs and cost reductions, including carrying costs, associated with the Utility’s use of natural gas derivative instruments are allowed to be passed on to the Utility’s customers through the operation of its Purchased Gas Adjustment (PGA) Clause, through which the MoPSC allows the Utility to recover gas supply costs, subject to prudence review by the MoPSC. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these derivative instruments. The Utility does not designate these instruments as hedging instruments for financial reporting purposes because gains or losses associated with the use of these derivative instruments are deferred and recorded as regulatory assets or regulatory liabilities pursuant to ASC Topic 980, “Regulated Operations,” and, as a result, have no direct impact on the Statements of Consolidated Income. The timing of the operation of the PGA Clause may cause interim variations in short-term cash flows, because the Utility is subject to cash margin requirements associated with changes in the values of these instruments. Nevertheless, carrying costs associated with such requirements are recovered through the PGA Clause.
From time to time, Laclede Gas purchases NYMEX futures and options contracts to help stabilize operating costs associated with forecasted purchases of gasoline and diesel fuels used to power vehicles and equipment used in the course of its business. At December 31, 2011, Laclede Gas held 0.2 million gallons of gasoline futures contracts at an average price of $2.92 per gallon and 0.4 million gallons of gasoline options contracts. Most of these contracts, the longest of which extends to September 2012, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815, “Derivatives and Hedging.” The gains or losses on these derivative instruments are not subject to the Utility’s PGA Clause.
In the course of its business, Laclede Group’s non-regulated gas marketing subsidiary, Laclede Energy Resources, Inc. (LER), enters into commitments associated with the purchase or sale of natural gas. Many of LER’s derivative natural gas contracts are designated as normal purchases or normal sales and, as such, are excluded from the scope of ASC Topic 815 and are accounted for as executory contracts on an accrual basis. Any of LER’s derivative natural gas contracts that are not designated as normal purchases or normal sales are accounted for at fair value. At December 31, 2011, the fair values of 31.6 million MMBtu of non-exchange traded natural gas commodity contracts were reflected in the Consolidated Balance Sheet. Of these contracts, 28.2 million MMBtu will settle during fiscal year 2012, while the remaining 3.4 million MMBtu will settle during fiscal year 2013. These contracts have not been designated as hedges; therefore, changes in the fair value of these contracts are reported in earnings each period. Furthermore, LER manages the price risk associated with its fixed-priced commitments by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of NYMEX or ICE futures and swap contracts to lock in margins. At December 31, 2011, LER’s unmatched fixed-price positions were not material to Laclede Group’s financial position or results of operations. LER’s NYMEX and ICE natural gas futures and swap contracts used to lock in margins are generally designated as cash flow hedges of forecasted transactions for financial reporting purposes.
Derivative instruments designated as cash flow hedges of forecasted transactions are recognized on the Consolidated Balance Sheets at fair value and the change in the fair value of the effective portion of these hedge instruments is recorded, net of tax, in other comprehensive income (OCI). Accumulated other comprehensive income (AOCI) is a component of Total Common Stock Equity. Amounts are reclassified from AOCI into earnings when the hedged items affect net income, using the same revenue or expense category that the hedged item impacts. Based on market prices at December 31, 2011, it is expected that approximately $1.0 million of pre-tax unrealized gains will be reclassified into the Statements of Consolidated Income during the next twelve months. 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.


The Company’s exchange-traded/cleared derivative instruments consist primarily of NYMEX and ICE positions. The NYMEX is the primary national commodities exchange on which natural gas derivatives are traded. Open NYMEX/ICE natural gas futures and swap positions at December 31, 2011 were as follows:

     
Laclede Gas Company
 
Laclede Energy
Resources, Inc.
 
     
MMBtu
(millions)
 
Avg. Price
Per
MMBtu
 
MMBtu
(millions)
 
Avg. Price
Per
MMBtu
 
 
Open short futures positions
                         
 
    Fiscal 2012
 
 
$
   
4.93
 
$
4.13
   
 
    Fiscal 2013
 
   
   
1.31
   
4.37
   
                             
 
Open long futures positions
                         
 
    Fiscal 2012
 
15.41
 
$
4.42
   
2.82
 
$
4.62
   
 
    Fiscal 2013
 
14.34
   
4.56
   
0.76
   
4.41
   
 
    Fiscal 2014
 
   
   
0.06
   
4.53
   

At December 31, 2011, Laclede Gas also had 5.2 million MMBtu of other price mitigation in place through the use of NYMEX natural gas option-based strategies.



The Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income
   
                   
                   
     
Three Months Ended
   
 
Location of Gain (Loss)
 
December 31,
   
(Thousands)
Recorded in Income
   
2011
   
2010
   
                   
Derivatives in Cash Flow Hedging Relationships
                 
                   
     Effective portion of gain recognized in OCI
                 
        on derivatives:
                 
             NYMEX/ICE natural gas contracts
   
$
2,997
 
$
41
   
             NYMEX gasoline and heating oil contracts
     
50
   
173
   
          Total
   
$
3,047
 
$
214
   
                   
     Effective portion of gain (loss) reclassified from
                 
        AOCI to income:
                 
             NYMEX/ICE natural gas contracts
Non-Regulated Gas Marketing Operating Revenues
 
$
6,740
 
$
4,834
   
 
Non-Regulated Gas Marketing Operating Expenses
   
(3,924
)
 
(1,793
)
 
                    Sub-total
     
2,816
   
3,041
   
                   
             NYMEX gasoline and heating oil contracts
Other Regulated Gas Distribution Operating Expenses
   
14
   
49
   
          Total
   
$
2,830
 
$
3,090
   
                   
     Ineffective portion of gain (loss) on derivatives
                 
        recognized in income:
                 
             NYMEX/ICE natural gas contracts
Non-Regulated Gas Marketing Operating Revenues
 
$
19
 
$
9
   
 
Non-Regulated Gas Marketing Operating Expenses
   
(106
)
 
(125
)
 
                    Sub-total
     
(87
)
 
(116
)
 
                   
             NYMEX gasoline and heating oil contracts
Other Regulated Gas Distribution Operating Expenses
   
6
   
29
   
          Total
   
$
(81
)
$
(87
)
 
                   
Derivatives Not Designated as Hedging Instruments *
               
                   
     Gain (loss) recognized in income on derivatives:
                 
                   
             Natural gas commodity contracts
Non-Regulated Gas Marketing Operating Revenues
 
$
(767
)
$
(442
)
 
 
Non-Regulated Gas Marketing Operating Expenses
   
687
   
450
   
             NYMEX/ICE natural gas contracts
Non-Regulated Gas Marketing Operating Revenues
   
70
   
(36
)
 
             NYMEX gasoline and heating oil contracts
Other Income and (Income Deductions) - Net
   
1
   
16
   
          Total
   
$
(9
)
$
(12
)
 

*
Gains and losses on Laclede Gas’ natural gas derivative instruments, which are not designated as hedging instruments for financial reporting purposes, are deferred pursuant to the Utility’s PGA Clause and initially recorded as regulatory assets or regulatory liabilities. These gains and losses are excluded from the table above because they have no direct impact on the Statements of Consolidated Income. Such amounts are recognized in the Statements of Consolidated Income as a component of Utility Natural and Propane Gas operating expenses when they are recovered through the PGA Clause and reflected in customer billings.




Fair Value of Derivative Instruments in the Consolidated Balance Sheet at December 31, 2011
 
   
Asset Derivatives
 
Liability Derivatives
 
(Thousands)
 
Balance Sheet Location
 
Fair
Value
*
Balance Sheet Location
 
Fair
Value
*
Derivatives designated as hedging instruments
             
  NYMEX/ICE natural gas contracts
 
Derivative Instrument Assets
$
3,124
 
Derivative Instrument Assets
$
2,021
 
   
Other Deferred Charges
 
220
 
Other Deferred Charges
 
148
 
  NYMEX gasoline and heating oil contracts
 
Accounts Receivable – Other
 
24
 
Accounts Receivable - Other
 
 
        Sub-total
     
3,368
     
2,169
 
                   
Derivatives not designated as hedging instruments
             
  NYMEX/ICE natural gas contracts
 
Accounts Receivable - Other
 
8
 
Accounts Receivable - Other
 
26,349
 
   
Derivative Instrument Assets
 
3
 
Derivative Instrument Assets
 
4
 
   
Other Deferred Charges
 
326
 
Other Deferred Charges
 
 
  Natural gas commodity contracts
 
Derivative Instrument Assets
 
2,229
 
Derivative Instrument Assets
 
100
 
   
Other Current Liabilities
 
 
Other Current Liabilities
 
47
 
  NYMEX gasoline and heating oil contracts
 
Accounts Receivable – Other
 
7
 
Accounts Receivable - Other
 
 
        Sub-total
     
2,573
     
26,500
 
  Total derivatives
   
$
5,941
   
$
28,669
 
                   
Fair Value of Derivative Instruments in the Consolidated Balance Sheet at September 30, 2011
 
   
Asset Derivatives
 
Liability Derivatives
 
(Thousands)
 
Balance Sheet Location
 
Fair
Value
*
Balance Sheet Location
 
Fair
Value
*
Derivatives designated as hedging instruments
             
  NYMEX/ICE natural gas contracts
 
Derivative Instrument Assets
$
4,395
 
Derivative Instrument Assets
$
4,105
 
   
Other Deferred Charges
 
4
 
Other Deferred Charges
 
85
 
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
 
15
 
Derivative Instrument Assets
 
117
 
        Sub-total
     
4,414
     
4,307
 
                   
Derivatives not designated as hedging instruments
             
  NYMEX/ICE natural gas contracts
 
Derivative Instrument Assets
 
457
 
Derivative Instrument Assets
 
16,330
 
   
Other Deferred Charges
 
 
Other Deferred Charges
 
408
 
  Natural gas commodity contracts
 
Derivative Instrument Assets
 
1,894
 
Derivative Instrument Assets
 
100
 
   
Other Deferred Charges
 
183
 
Other Deferred Charges
 
 
   
Other Current Liabilities
 
8
 
Other Current Liabilities
 
62
 
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
 
4
 
Derivative Instrument Assets
 
7
 
        Sub-total
     
2,546
     
16,907
 
  Total derivatives
   
$
6,960
   
$
21,214
 
                   



Fair Value of Derivative Instruments in the Consolidated Balance Sheet at December 31, 2010
 
   
Asset Derivatives
 
Liability Derivatives
 
(Thousands)
 
Balance Sheet Location
 
Fair
Value
*
Balance Sheet Location
 
Fair
Value
*
Derivatives designated as hedging instruments
             
  NYMEX/ICE natural gas contracts
 
Derivative Instrument Assets
$
1,102
 
Derivative Instrument Assets
$
11,088
 
   
Other Deferred Charges
 
21
 
Other Deferred Charges
 
1,240
 
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
 
169
 
Derivative Instrument Assets
 
 
        Sub-total
     
1,292
     
12,328
 
                   
Derivatives not designated as hedging instruments
             
  NYMEX/ICE natural gas contracts
 
Derivative Instrument Assets
 
2,289
 
Derivative Instrument Assets
 
23,180
 
   
Other Deferred Charges
 
94
 
Other Deferred Charges
 
245
 
  Natural gas commodity contracts
 
Derivative Instrument Assets
 
201
 
Derivative Instrument Assets
 
4
 
   
Other Deferred Charges
 
14
 
Other Deferred Charges
 
 
   
Other Current Liabilities
 
50
 
Other Current Liabilities
 
85
 
  NYMEX gasoline and heating oil contracts
 
Derivative Instrument Assets
 
13
 
Derivative Instrument Assets
 
 
        Sub-total
     
2,661
     
23,514
 
  Total derivatives
   
$
3,953
   
$
35,842
 

*
The fair values of Asset Derivatives and Liability Derivatives exclude the fair value of cash margin receivables or payables with counterparties subject to netting arrangements. Fair value amounts of derivative contracts (including the fair value amounts of cash margin receivables and payables) for which there is a legal right to set off are presented net on the Consolidated Balance Sheets. As such, the gross balances presented in the table above are not indicative of the Company’s net economic exposure. Refer to Note 6 , Fair Value Measurements, for information on the valuation of derivative instruments.

Following is a reconciliation of the amounts in the tables above to the amounts presented in the Consolidated Balance Sheets:

     
Dec. 31,
 
Sept. 30,
 
Dec. 31,
 
 
(Thousands)
 
2011
 
2011
 
2010
 
                       
 
Fair value of asset derivatives presented above
 
$
5,941
 
$
6,960
 
$
3,953
 
 
Fair value of cash margin receivables offset with derivatives
   
26,310
   
23,188
   
47,269
 
 
Netting of assets and liabilities with the same counterparty
   
(28,621
)
 
(21,160
)
 
(35,807
)
 
    Total
 
$
3,630
 
$
8,988
 
$
15,415
 
                       
 
Derivative Instrument Assets, per Consolidated Balance Sheets:
                   
 
  Derivative instrument assets
 
$
3,232
 
$
7,759
 
$
13,150
 
 
  Other deferred charges
   
398
   
1,229
   
2,265
 
 
    Total
 
$
3,630
 
$
8,988
 
$
15,415
 
                       
 
Fair value of liability derivatives presented above
 
$
28,669
 
$
21,214
 
$
35,842
 
 
Netting of assets and liabilities with the same counterparty
   
(28,621
)
 
(21,160
)
 
(35,807
)
 
    Derivative instrument liabilities, per Consolidated Balance Sheets*
 
$
48
 
$
54
 
$
35
 
                       
*
Included in the Other line of the Current Liabilities section
                   





8 .
CONCENTRATIONS OF CREDIT RISK

A significant portion of LER’s transactions are with (or are associated with) energy producers, utility companies, and pipelines. These concentrations of transactions with these counterparties have the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. To manage this risk, as well as credit risk from significant counterparties in these and other industries, LER has established procedures to determine the creditworthiness of its counterparties. These procedures include obtaining credit ratings and credit reports, analyzing counterparty financial statements to assess financial condition, and considering the industry environment in which the counterparty operates. This information is monitored on an ongoing basis. In some instances, LER may require credit assurances such as prepayments, letters of credit, or parental guarantees. In addition, LER may enter into netting arrangements to mitigate credit risk with counterparties in the energy industry from which LER both sells and purchases natural gas. Sales are typically made on an unsecured credit basis with payment due the month following delivery. Accounts receivable amounts are closely monitored and provisions for uncollectible amounts are accrued when losses are probable. To date, losses have not been significant. LER records accounts receivable, accounts payable, and prepayments for physical sales and purchases of natural gas on a gross basis. The amount included in accounts receivable attributable to energy producers and their marketing affiliates amounted to $14.8 million, or 30.9% of LER’s total accounts receivable at December 31, 2011. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $11.5 million. Accounts receivable attributable to utility companies and their marketing affiliates comprised $20.0 million of LER’s total accounts receivable, or 41.9% at December 31, 2011, while net receivable amounts from these customers, reflecting netting arrangements, were $17.0 million. LER also has concentrations of credit risk with certain individually significant counterparties. At December 31, 2011, the amounts included in accounts receivable from LER’s five largest counterparties (in terms of net accounts receivable exposure), were $17.0 million, or 35.4% of LER’s total accounts receivable. These five counterparties are either investment-grade rated or owned by investment-grade rated companies. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $14.6 million. Additionally, LER has concentrations of credit risk with pipeline companies associated with its natural gas receivable amounts.


9 .
OTHER INCOME AND (INCOME DEDUCTIONS) – NET


     
Three Months Ended
 
     
December 31,
 
 
(Thousands)
 
2011
 
2010
 
                 
 
Interest income
 
$
348
 
$
448
 
 
Net investment gain
   
1,030
   
737
 
 
Other income
   
   
13
 
 
Other income deductions
   
561
   
647
 
 
Other Income and (Income Deductions) – Net
 
$
1,939
 
$
1,845
 







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 2.2 million, including the City of St. Louis and parts of ten 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, and LER Storage Services, Inc., which was formed in October 2011 to utilize natural gas storage contracts for providing natural gas sales, but was not yet operational as of December 31, 2011. 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 business activities, which are comprised of its non-regulated propane sales transactions and its propane storage and related services. Accounting policies are described in Note 1 . Certain intersegment revenues with Laclede Gas are not eliminated in accordance with the provisions of ASC Topic 980. 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.
Management evaluates the performance of the operating segments based on the computation of net economic earnings. Net economic earnings exclude from reported net income the after-tax impacts of net unrealized gains and losses and other timing differences associated with energy-related transactions. Net economic earnings will also exclude, if applicable, the after-tax impact of costs related to acquisition, divestiture, and restructuring activities.




       
Non-
             
   
Regulated
 
Regulated
             
   
Gas
 
Gas
             
(Thousands)
 
Distribution
 
Marketing
 
Other
 
Eliminations
 
Consolidated
 
Three Months Ended
                               
December 31, 2011
                               
Revenues from external
                               
    customers
 
$
250,899
 
$
151,977
 
$
1,163
 
$
 
$
404,039
 
Intersegment revenues
   
3
   
6,611
   
260
   
   
6,874
 
Total Operating Revenues
   
250,902
   
158,588
   
1,423
   
   
410,913
 
Net Economic Earnings
   
21,079
   
3,439
   
375
   
   
24,893
 
Total assets
   
1,753,859
   
167,879
   
137,768
   
(185,176
)
 
1,874,330
 
                                 
Three Months Ended
                               
December 31, 2010
                               
Revenues from external
                               
    customers
 
$
276,505
 
$
157,701
 
$
91
 
$
 
$
434,297
 
Intersegment revenues
   
938
   
8,707
   
260
   
   
9,905
 
Total Operating Revenues
   
277,443
   
166,408
   
351
   
   
444,202
 
Net Economic Earnings
   
21,434
   
1,946
   
8
   
   
23,388
 
Total assets
   
1,734,389
   
166,394
   
121,235
   
(177,791
)
 
1,844,227
 

Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income
 
     
Three Months Ended
 
     
December 31,
 
 
(Thousands)
 
2011
 
2010
 
                 
 
Total Net Economic Earnings above
 
$
24,893
 
$
23,388
 
 
  Add: Unrealized gain (loss) on energy-related
             
 
    derivative contracts, net of tax
   
281
   
(19
)
 
Net Income
 
$
25,174
 
$
23,369
 




COMMITMENTS AND CONTINGENCIES

Commitments

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 December 31, 2011 are estimated at approximately $496 million. Additional contracts are generally entered into prior to or during the heating season. Laclede Gas recovers its costs from customers in accordance with the PGA Clause.
During fiscal 2011, the Utility initiated a multi-year project to replace its existing work management, financial, and supply chain software applications to enhance its technology, customer service, and business processes. At December 31, 2011, the Company was contractually committed to costs of approximately $8 million related to this project, with additional expenditures to be incurred throughout the project’s life.

Leases and Guarantees

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 into 2015. At December 31, 2011, the maximum guarantees under these leases are $0.9 million. However, the Utility believes it is unlikely that it will be subject to the maximum payment amount because it estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At December 31, 2011, the carrying value of the liability recognized for these guarantees was $0.2 million.
Laclede Group had guarantees totaling $96.3 million for performance and payment of certain gas supply transactions by LER, as of December 31, 2011. Since that date, total guarantees issued by Laclede Group on behalf of LER increased by $1.0 million, bringing the total to $97.3 million in guarantees outstanding at January 27, 2012. No amounts have been recorded for these guarantees in the financial statements. As of December 31, 2011, management believes the probability is low that Laclede Group will be required to make payments under these guarantees.

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.
Similar to other natural gas utility companies, Laclede Gas faces the risk of incurring environmental liabilities. In the natural gas industry, these are typically associated with sites formerly owned or operated by gas distribution companies like Laclede Gas and/or its predecessor companies at which manufactured gas operations took place. At this time, Laclede Gas has identified three former manufactured gas plant (MGP) sites where costs have been incurred and claims have been asserted: one in Shrewsbury, Missouri and two in the City of St. Louis, Missouri.
With regard to the former MGP site located in Shrewsbury, Missouri, Laclede Gas and state and federal environmental regulators agreed upon certain remedial actions to a portion of the site in a 1999 Administrative Order on Consent (AOC), which actions have been completed. On September 22, 2008, EPA Region VII issued a letter of Termination and Satisfaction terminating the AOC. However, if after this termination of the AOC, regulators require additional remedial actions, or additional claims are asserted, Laclede Gas may incur additional costs.
One of the sites located in the City of St. Louis is currently owned by a development agency of the City, which, together with other City development agencies, has selected a developer to redevelop the site. In conjunction with this redevelopment effort, Laclede Gas and another former owner of the site entered into an agreement (Remediation Agreement) with the City development agencies, the developer, and an environmental consultant that obligates one of the City agencies and the environmental consultant to remediate the site and obtain a No Further Action letter from the Missouri Department of Natural Resources. The Remediation Agreement also provides for a release of Laclede Gas and the other former site owner from certain liabilities related to the past and current environmental condition of the site and requires the developer and the environmental consultant to maintain certain insurance coverages, including remediation cost containment, premises pollution liability, and professional liability. The operative provisions of the Remediation Agreement were triggered on December 20, 2010, on which date Laclede Gas and the other former site owner, as full consideration under the Remediation Agreement, paid a small percentage of the cost of remediation of the site. The amount paid by Laclede Gas, which is its only monetary obligation under the Remediation Agreement, did not materially impact the financial condition, results of operations, or cash flows of the Company.
 
 
Laclede Gas has not owned the other site located in the City of St. Louis for many years. In a letter dated June 29, 2011, the Attorney General for the State of Missouri informed Laclede Gas that the Missouri Department of Natural Resources had completed an investigation of the site. The Attorney General requested that Laclede Gas participate in the follow up investigations of the site. In a letter dated January 10, 2012, the Company stated that it would participate in future environmental response activities at the site assuming that other potentially responsible parties are willing to contribute to such efforts in a meaningful and equitable fashion.
To date, amounts required for remediation at these sites have not been material. However, the amount of costs relative to future remedial actions at these and other sites is unknown and may be material. Laclede Gas has notified its insurers that it seeks reimbursement for costs incurred in the past and future potential liabilities associated with the MGP sites. While some of the insurers have denied coverage and reserved their rights, Laclede Gas continues to discuss potential reimbursements with them. In 2005, the Utility’s outside consultant completed an analysis of the MGP sites to determine cost estimates for a one-time contractual transfer of risk from each of the Utility’s insurers of environmental coverage for the MGP sites. That analysis demonstrated a range of possible future expenditures to investigate, monitor, and remediate these MGP sites from $5.8 million to $36.3 million based upon then currently available facts, technology, and laws and regulations. The actual costs that Laclede Gas may incur could be materially higher or lower depending upon several factors, including whether remedial actions will be required, final selection and regulatory approval of any remedial actions, changing technologies and governmental regulations, the ultimate ability of other potentially responsible parties to pay, the successful completion of remediation efforts required by the Remediation Agreement described above, and any insurance recoveries. Costs associated with environmental remediation activities are accrued when such costs are probable and reasonably estimable.
Laclede Gas anticipates that any costs it may incur in the future to remediate these sites, less any amounts received as insurance proceeds or as contributions from other potentially responsible parties, would be deferred and recovered in rates through periodic adjustments approved by the MoPSC. Accordingly, any potential liabilities that may arise with remediating these sites are not expected to have a material impact on the future financial position and results of operations of Laclede Gas or the Company.
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 year 2005, which the Staff later reduced to a $1.7 million disallowance pertaining to Laclede Gas’ purchase of gas from a marketing affiliate, LER. The MoPSC Staff has also proposed disallowances of $2.8 million and $1.5 million of gas costs relating to Laclede Gas purchases of gas supply from LER for fiscal years 2006 and 2007, respectively. The MoPSC Staff proposed a number of non-monetary recommendations, based on its review of gas costs for fiscal years 2008 and 2009. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments in proceedings before the MoPSC. As such, no amount has been recorded in the financial statements for these proposed disallowances.
In connection with the affiliate transactions mentioned above, on July 7, 2010, the MoPSC Staff filed a complaint against Laclede Gas alleging that, by stating that it was not in possession of proprietary LER documents, Laclede Gas violated the MoPSC Order authorizing the holding company structure (2001 Order). Laclede Gas counterclaimed that the Staff failed to adhere to the pricing provisions of the MoPSC’s affiliate transaction rules and Laclede Gas’ Cost Allocation Manual. By orders dated November 3, 2010 and February 4, 2011, respectively, the MoPSC dismissed Laclede’s counterclaim and granted summary judgment to Staff, finding that Laclede Gas violated the terms of the 2001 Order and authorizing its General Counsel to seek penalties in court against Laclede Gas. On March 30, 2011, Laclede Gas sought review of the February 4 Order with the Missouri Cole County Circuit Court. On May 19, 2011, the Commission’s General Counsel filed a petition with the Cole County Circuit Court seeking penalties in connection with the Commission’s February 4 Order. On July 7, 2011, the Circuit Court Judge signed an agreed Order holding the penalty case in abeyance while the February 4 Order is appealed. On December 21, 2011, the Circuit Court reversed both the MoPSC’s November 3, 2010 Order and its February 4, 2011 Order.
Subsequent to the July 7, 2010 complaint, the MoPSC Staff filed a related complaint on October 6, 2010 against Laclede Gas, LER, and Laclede Group, alleging that the Utility has failed to comply with the MoPSC’s affiliate transaction rules. LER and Laclede Group both filed motions to be dismissed from the proceeding, which were granted by the Commission on December 22, 2010. On January 26, 2011, the Commission also dismissed certain counts of the complaint against Laclede Gas. The remaining counts and a counterclaim against the Staff, filed by Laclede Gas, are still pending before the Commission. Laclede Gas believes that the complaint lacks merit and is vigorously opposing it.
On June 29, 2010, the Office of Federal Contract Compliance Programs issued a Notice of Violations to Laclede Gas alleging lapses in certain employment selection procedures during a two-year period ending in February 2006. The Company believes that the allegations lack merit and is vigorously defending its position. Management, after discussion with counsel, believes that the final outcome of these matters will not have a material effect on the consolidated financial position and results of operations of the Company.


As discussed in Note 7 , Derivative Instruments and Hedging Activities, Laclede Gas and LER enter into NYMEX and ICE exchange-traded/cleared derivative instruments. Previously, these instruments were held in accounts at MF Global, Inc. On October 31, 2011, affiliated entities of MF Global filed a Chapter 11 petition at the U.S. Bankruptcy Court in the Southern District of New York. Subsequently, the court-appointed bankruptcy trustee transferred all of the open positions and a significant portion of the margin deposits of Laclede Gas and LER to a new brokerage firm. As of January 26, 2012, Laclede Gas and LER had $1.5 million and $0.5 million, respectively, on deposit with MF Global in customer-segregated accounts that remain unavailable pending final resolution by the bankruptcy trustee. While the Company’s total exposure at this time is not considered material, management is unable to predict when, or to what extent, these remaining funds will be returned.
Laclede Group is involved in other litigation, claims, and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcome will not have a material effect on the consolidated financial position, results of operations, or cash flows of the Company.


Item 1A . Risk Factors

The following paragraphs should be read in conjunction with the risk factors included in Part I, Item 1A of the Company’s Annual Report on Form 10-K for the year ended September 30, 2011.

RISKS THAT RELATE TO THE NON-REGULATED GAS MARKETING SEGMENT

Increased competition, regional fluctuations in natural gas commodity prices, and pipeline infrastructure projects may adversely impact LER’s future profitability.

Competition in the marketplace and regional fluctuations in natural gas commodity prices have a direct impact on LER’s business. Changing market conditions, the narrowing of regional and seasonal price differentials, and limited future price volatility may adversely impact LER’s sales margins or affect LER’s ability to procure gas supplies and/or to serve certain customers, which may reduce sales profitability and/or increase certain credit requirements caused by reductions in netting capability. Although the FERC regulates the interstate transportation of natural gas and establishes the general terms and conditions under which LER may use interstate gas pipeline capacity to purchase and transport natural gas, LER must occasionally renegotiate its transportation agreements with a concentrated group of pipeline companies. Renegotiated terms of new agreements may impact LER’s future profitability. Profitability may also be adversely impacted if pipeline capacity or future storage capacity secured by LER is not fully utilized and/or its costs are not fully recovered.

Risk management policies, including the use of derivative instruments, may not fully protect LER’s sales and results of operations from volatility and may result in financial losses.

In the course of its business, LER enters into contracts to purchase and sell natural gas at fixed prices and index-based prices. Commodity price risk associated with these contracts has the potential to impact earnings and cash flows. To minimize this risk, LER has a risk management policy that provides for daily monitoring of a number of business measures, including fixed price commitments. LER currently manages the commodity price risk associated with fixed-price commitments for the purchase or sale of natural gas by either closely matching the offsetting physical purchase or sale of natural gas at fixed prices or through the use of natural gas futures and swap contracts traded on or cleared through the NYMEX and ICE to lock in margins. These exchange-traded/cleared contracts are generally designated as cash flow hedges of forecasted transactions. However, market conditions and regional price changes may cause ineffective portions of matched positions to result in financial losses. Additionally, to the extent that LER’s natural gas commitments do not qualify for the normal purchases or normal sales designation (or the designation is not elected), the contracts are recorded as derivatives at fair value each period. Accordingly, the associated gains and losses are reported directly in earnings and may cause volatility in results of operations. Depending on the circumstances, gains or losses (realized and unrealized) on these contracts may be required to be presented on a net basis (instead of a gross basis) in the statements of consolidated income. Such presentation could result in reductions to and/or volatility in the Company’s operating revenues.



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

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 changes in natural gas prices, including the related impact on margin deposits associated with the use of natural gas derivative instruments;
the impact of changes and volatility in 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, including decisions by natural gas producers to reduce production or shut in producing natural gas wells as well as other changes that impact supply for and access to the markets in which our subsidiaries transact business;
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
 
regulatory assets
 
non-regulated and affiliate transactions
 
franchise renewals
 
environmental or safety matters, including the potential impact of legislative and regulatory actions related to climate change and pipeline safety
 
taxes
 
pension and other postretirement benefit liabilities and funding obligations
 
accounting standards, including the effect of potential changes relative to adoption of or convergence with international 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 with reasonable terms 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.





RESULTS OF OPERATIONS

Overview

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 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 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 typically concentrated in the November through April period, which generally corresponds with the heating season.

Laclede Energy Resources, Inc. (LER) is engaged in the marketing of natural gas and related activities on a non-regulated basis. 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. LER’s operations and customer base are more subject to fluctuations in market conditions than the Utility.

In October 2011, LER formed a wholly owned subsidiary, LER Storage Services, Inc. (LSS), to utilize natural gas storage contracts for providing natural gas sales, but was not yet operational as of December 31, 2011. Effective January 1, 2012, LSS contracted for 1 Bcf of natural gas storage capacity for a thirteen month period through January 2013, and purchased 1 Bcf of natural gas in place during January 2012 for $3.0 million.  Further, and separately, LSS has entered into a precedent agreement with a natural gas storage facility operator that will provide 1 Bcf of natural gas storage subject to the facility’s successful completion of an expansion program in early to mid-2013.

Other subsidiaries provide less than 10% of consolidated revenues.
 
On January 26, 2012, Laclede Group’s Board of Directors named Mr. William E. Nasser as Chairman of the Board and appointed Ms. Suzanne Sitherwood, currently President, as Chief Executive Officer (CEO). Ms. Sitherwood will also serve as Laclede Gas Company’s Chairman, President and CEO. These appointments are all effective February 1, 2012, concurrent with Mr. Douglas H. Yaeger’s retirement.
 
Based on the nature of the business of the Company and its subsidiaries, as well as current economic conditions, management focuses on the following key variables in evaluating the financial condition and results of operations and managing the business:

Regulated Gas Distribution Segment:

the Utility’s ability to recover the costs of purchasing and distributing natural gas from its customers;
the impact of weather and other factors, such as customer conservation, on revenues and expenses;
changes in the regulatory environment at the federal, state, and local levels, as well as decisions by regulators, that impact the Utility’s ability to earn its authorized rate of return;
the Utility’s ability to access credit markets and maintain working capital sufficient to meet operating requirements; and,
the effect of natural gas price volatility on the business.

Non-Regulated Gas Marketing Segment:

the risks of competition;
regional and seasonal fluctuations in natural gas prices;
new national pipeline infrastructure projects;
the ability to procure firm transportation and storage services at reasonable rates;
 
 
 
 
 
 
credit and/or capital market access;
counterparty risks;
the effect of natural gas price volatility on the business; and,
pursuing additional growth.

Further information regarding how management seeks to manage these key variables is discussed below.

Laclede Gas continues to provide reliable natural gas service at a reasonable cost, while maintaining and building a secure and dependable infrastructure. The Utility’s strategy focuses on improving performance and mitigating the impact of weather fluctuations on Laclede Gas’ customers while improving the ability to recover its authorized distribution costs and return. The Utility’s distribution costs are the essential, primarily fixed, expenditures it must incur to operate and maintain more than 16,000 miles of mains and services comprising its natural gas distribution system and related storage facilities. The Utility’s distribution costs include wages and employee benefit costs, depreciation and maintenance expenses, and other regulated utility operating expenses, excluding natural and propane gas expense. Distribution costs are considered in the ratemaking process, and recovery of these types of costs is included in revenues generated through the Utility’s tariff rates, as approved by the MoPSC. The settlement of the Utility’s rate case in 2010 retained the Utility’s weather mitigation rate design that better ensures 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 and capacity release remains subject to fluctuations in market conditions. 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. See the Regulatory and Other Matters section on page 36 of this report for additional information on regulatory issues relative to the Utility.

Laclede Gas works actively to reduce the impact of wholesale natural gas price volatility on its costs by strategically structuring its natural gas supply portfolio to increase its gas supply availability and pricing alternatives and through the use of derivative instruments to protect its customers from significant changes in the commodity price of natural gas. Nevertheless, the overall cost of purchased gas remains subject to fluctuations in market conditions. The Utility’s Purchased Gas Adjustment (PGA) Clause allows Laclede Gas to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies, including costs, cost reductions, and related carrying costs associated with the use of derivative 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 price of natural gas supplies and other economic conditions may 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.

The Utility relies on both short-term credit and long-term capital markets, as well as cash flows from operations, to satisfy its seasonal cash requirements and fund its cost of capital expenditures. Laclede Gas’ ability to issue commercial paper supported by lines of credit, to issue long-term bonds, or to obtain new lines of credit is dependent on current conditions in the credit and capital markets. Management focuses on maintaining a strong balance sheet and believes it currently has adequate access to credit and capital markets and will have sufficient capital resources to meet its foreseeable obligations. See the Liquidity and Capital Resources section on page 38 for additional information.

LER provides both on-system Utility transportation customers and customers outside of Laclede Gas’ traditional service area with another choice in non-regulated natural gas suppliers. LER utilizes its natural gas supply agreements, transportation agreements, storage agreements, and other executory contracts to support a variety of services to its customers at competitive prices. It closely monitors and manages the natural gas commodity price risk associated with providing such services to its customers through the use of exchange-traded/cleared derivative instruments and other contractual arrangements. LER is committed to managing commodity price risk, while it seeks to expand the services that it now provides. Nevertheless, income from LER’s operations is more subject to fluctuations in market conditions than the Utility’s operations. LER’s business is directly impacted by the effects of competition in the marketplace, the impact of new pipeline infrastructure, and surplus natural gas supplies on regional natural gas commodity prices.

 
 
 
 
In the course of its business, LER enters into commitments associated with the purchase or sale of natural gas. Many of LER’s physical purchase and sale transactions are recognized in earnings when the natural gas is delivered. However, generally accepted accounting principles (GAAP) require that some of LER’s energy-related transactions be accounted for as derivatives, with the changes in their fair value (representing unrealized gains or losses) recorded in earnings in periods prior to physical delivery. Because related transactions of a purchase and sale strategy may be accounted for differently, there may be timing differences in the recognition of earnings under GAAP and economic earnings realized upon settlement. The Company reports both GAAP and net economic earnings, as discussed below.

In addition to its operating cash flows, LER relies on Laclede Group’s parental guarantees to secure its purchase and sales obligations of natural gas. LER also has access to Laclede Group’s liquidity resources. A large portion of LER’s receivables are from customers in the energy industry. LER also enters into netting arrangements with many of its energy counterparties to reduce overall credit and collateral exposure. Although LER’s uncollectible amounts are closely monitored and have not been significant, increases in uncollectible amounts from customers are possible and could adversely affect LER’s liquidity and results.

LER carefully monitors the creditworthiness of counterparties to its transactions. LER performs in-house credit reviews of potential customers and may require credit assurances such as prepayments, letters of credit, or parental guarantees when appropriate. Credit limits for customers are established and monitored.


EARNINGS

The Laclede Group reports net income and earnings per share determined in accordance with GAAP. Management also uses the non-GAAP measures of net economic earnings and net economic earnings per share when internally evaluating results of operations. These non-GAAP measures exclude from net income the after-tax impacts of fair value accounting adjustments and other timing adjustments associated with energy-related transactions. These adjustments include timing differences where the accounting treatment differs from the economic substance of the underlying transaction, including the following:

Net unrealized gains and losses on energy-related derivatives that are required by GAAP fair value accounting associated with current changes in the fair value of financial and physical transactions prior to their completion and settlement. These unrealized gains and losses result primarily from two sources:
     
 
1)
changes in the fair values of physical and/or financial derivatives prior to the period of settlement; and,
 
2)
ineffective portions of accounting hedges, required to be recorded in earnings prior to settlement, due to differences in commodity price changes between the locations of the forecasted physical purchase or sale transactions and the locations of the underlying hedge instruments;
   
Lower of cost or market adjustments to the carrying value of commodity inventories resulting when the market price of the commodity falls below its original cost, to the extent that those commodities are economically hedged; and,
Realized gains and losses resulting from the settlement of economic hedges prior to the sale of the physical commodity.

These adjustments eliminate the impact of timing differences, including the impact of current changes in the fair value of financial and physical transactions prior to their completion and settlement. Unrealized gains or losses are recorded in each period until being replaced with the actual gains or losses realized when the associated physical transaction(s) occur. While management uses these non-GAAP measures to evaluate both Laclede Gas and LER, the net effect of adjustments on the Utility’s earnings is minimal because gains or losses on its natural gas derivative instruments are deferred pursuant to its PGA Clause, as authorized by the MoPSC.

 Management believes that excluding the earnings volatility caused by recognizing changes in fair value prior to settlement and other timing differences associated with related purchase and sale transactions provides a useful representation of the economic effects of only the actual settled transactions and their effects on results of operations. In addition, management will exclude the effect of costs related to unique acquisition, divestiture, and restructuring activities, if any, when evaluating on-going performance, and therefore will exclude these costs from net economic earnings. These internal non-GAAP operating metrics should not be considered as an alternative to, or more meaningful
 
 
than, GAAP measures such as net income. Reconciliations of net economic earnings and net economic earnings per share to the Company’s most directly comparable GAAP measures are provided below.

(Millions, except per share amounts)
Net Economic Earnings
(Non-GAAP)
Add: Unrealized gain (loss) on energy-related derivative contracts*
Net Income
(GAAP)
                         
Quarter Ended December 31, 2011
                       
 
Regulated Gas Distribution
 
$
21.1
   
$
   
$
21.1
 
 
Non-Regulated Gas Marketing
   
3.4
     
0.3
     
3.7
 
 
Other
   
0.4
     
     
0.4
 
 
    Total
 
$
24.9
   
$
0.3
   
$
25.2
 
 
Per Share Amounts **
 
$
1.11
   
$
0.01
   
$
1.12
 
                         
Quarter Ended December 31, 2010
                       
 
Regulated Gas Distribution
 
$
21.5
   
$
   
$
21.5
 
 
Non-Regulated Gas Marketing
   
1.9
     
     
1.9
 
 
Other
   
     
     
 
 
    Total
 
$
23.4
   
$
   
$
23.4
 
 
Per Share Amounts **
 
$
1.05
   
$
   
$
1.05
 
                           
*
Amounts presented net of income taxes. Income taxes are calculated by applying federal, state, and local income tax rates applicable to ordinary income to the amounts of unrealized gain (loss) on energy-related derivative contracts. For the quarter ended December 31, 2011, the amount of income tax expense included in the reconciling item above is $0.2 million.
   
**
Net economic earnings per share is calculated by replacing consolidated net income with consolidated net economic earnings in the GAAP diluted earnings per share calculation.

Laclede Group’s net income was $25.2 million for the quarter ended December 31, 2011, compared with $23.4 million for the quarter ended December 31, 2010. Basic and diluted earnings per share for the quarter ended December 31, 2011 were $1.13 and $1.12, respectively, compared with basic and diluted earnings per share of $1.05 for the quarter ended December 31, 2010. Earnings increased compared to last year primarily due to improved results reported by Laclede Group’s Non-Regulated Gas Marketing Segment. Net economic earnings were $24.9 million for the quarter ended December 31, 2011 compared with $23.4 million for the same quarter last year. Net economic earnings per share were $1.11 for the quarter ended December 31, 2011 compared with $1.05 for the quarter ended December 31, 2010.

Both Regulated Gas Distribution net income and net economic earnings decreased by $0.4 million for the quarter ended December 31, 2011, compared with the quarter ended December 31, 2010. Quantified on a pre-tax basis, the decrease was primarily attributable to increases in pension expenses totaling $1.8 million, partially offset by higher Infrastructure System Replacement Surcharge (ISRS) revenues totaling $1.2 million.

The Non-Regulated Gas Marketing segment reported GAAP earnings totaling $3.7 million, an increase of $1.8 million compared with the same quarter last year. Net economic earnings for the three months ended December 31, 2011 increased $1.5 million from the three months ended December 31, 2010. These increases were primarily due to higher margins attributable to reduced transportation costs resulting from the renegotiation of contracts that were renewed during fiscal year 2011.

Regulated Gas Distribution Operating Revenues

Laclede Gas passes on to Utility customers (subject to prudence review by the MoPSC) 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 Gas Distribution Operating Revenues for the quarter ended December 31, 2011 were $250.9 million, or $26.5 million less than the same period last year. Temperatures experienced in the Utility’s service area during the quarter were 20.8% warmer than the same quarter last year and 22.1% warmer than normal. Total system therms sold and transported were 238.6 million for the quarter ended December 31, 2011 compared with 285.9 million for the same period last year. Total off-system therms sold and transported were 98.2 million for the quarter ended December 31, 2011 compared with 53.7 million for the same period last year. The decrease in Regulated Gas Distribution Operating Revenues was primarily attributable to the following factors:

(Millions)
 
Lower system sales volumes and other variations
 
$
(29.7
)
Higher off-system sales volumes (reflecting more favorable market conditions as described in greater
   detail in the Results of Operations)
   
17.7
 
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)
   
(10.0
)
Lower prices charged for off-system sales
   
(5.7
)
Higher ISRS revenues
   
1.2
 
Total Variation
 
$
(26.5
)

Regulated Gas Distribution Operating Expenses

Regulated Gas Distribution Operating Expenses for the quarter ended December 31, 2011 decreased $25.4 million from the same quarter last year. Natural and propane gas expense decreased $26.6 million, or 15.4%, from last year’s level, primarily attributable to decreased system volumes purchased for sendout and lower rates charged by our suppliers, partially offset by higher off-system gas expense. Other operation and maintenance expenses increased $1.9 million, or 4.6%, primarily due to increased pension and compensation expenses, partially offset by decreased maintenance charges. Taxes, other than income taxes, decreased $1.1 million, or 6.9%, primarily due to decreased gross receipts taxes (attributable to the decreased revenues).

Non-Regulated Gas Marketing Operating Revenues and Operating Expenses

Non-Regulated Gas Marketing Operating Revenues decreased $7.8 million primarily due to lower per unit gas prices charged by LER. LER’s sales volumes during the quarter ended December 31, 2011 were essentially unchanged from the same period last year. The decrease in Non-Regulated Gas Marketing Operating Expenses, totaling $10.8 million, was primarily associated with lower prices charged by suppliers and reduced transportation expenses.

Other Income and (Income Deductions) - Net

Other Income and (Income Deductions) – Net increased $0.1 million primarily due to higher net investment gains, largely offset by a decrease in 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 $0.4 million decrease in interest charges was primarily due to lower interest on long-term debt, attributable to the November 2010 maturity of $25 million principal amount of 6 1/2 % first mortgage bonds, and lower interest on short-term debt. Average short-term interest rates were 0.3% for the quarter ended December 31, 2011 compared with 0.4% for the quarter ended December 31, 2010. Average short-term borrowings were $81.2 million for the quarter ended December 31, 2011 compared with $127.9 million for the quarter ended December 31, 2010.

Income Taxes

The $1.0 million increase in income taxes was primarily due to higher pre-tax income.


R EGULATORY AND OTHER MATTERS

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 year 2005, which the Staff later reduced to a $1.7 million disallowance pertaining to Laclede Gas’ purchase of gas from a marketing affiliate, LER. The MoPSC Staff has also proposed disallowances of $2.8 million and $1.5 million of gas costs relating to Laclede Gas purchases of gas supply from LER for fiscal years 2006 and 2007, respectively. The MoPSC Staff proposed a number of non-monetary recommendations, based on its review of gas costs for fiscal years 2008 and 2009. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments in proceedings before the MoPSC. As such, no amount has been recorded in the financial statements for these proposed disallowances.

In connection with the affiliate transactions mentioned above, on July 7, 2010, the MoPSC Staff filed a complaint against Laclede Gas alleging that, by stating that it was not in possession of proprietary LER documents, Laclede Gas violated the MoPSC Order authorizing the holding company structure (2001 Order). Laclede Gas counterclaimed that the Staff failed to adhere to the pricing provisions of the MoPSC’s affiliate transaction rules and Laclede Gas’ Cost Allocation Manual. By orders dated November 3, 2010 and February 4, 2011, respectively, the MoPSC dismissed Laclede’s counterclaim and granted summary judgment to Staff, finding that Laclede Gas violated the terms of the 2001 Order and authorizing its General Counsel to seek penalties in court against Laclede Gas. On March 30, 2011, Laclede Gas sought review of the February 4 Order with the Missouri Cole County Circuit Court. On May 19, 2011, the Commission’s General Counsel filed a petition with the Cole County Circuit Court seeking penalties in connection with the Commission’s February 4 Order. On July 7, 2011, the Circuit Court Judge signed an agreed Order holding the penalty case in abeyance while the February 4 Order is appealed. On December 21, 2011, the Circuit Court reversed both the MoPSC’s November 3, 2010 Order and its February 4, 2011 Order.

Subsequent to the July 7, 2010 complaint, the MoPSC Staff filed a related complaint on October 6, 2010 against Laclede Gas, LER, and Laclede Group, alleging that the Utility has failed to comply with the MoPSC’s affiliate transaction rules. LER and Laclede Group both filed motions to be dismissed from the proceeding, which were granted by the Commission on December 22, 2010. On January 26, 2011, the Commission also dismissed certain counts of the complaint against Laclede Gas. The remaining counts and a counterclaim against the Staff, filed by Laclede Gas, are still pending before the Commission. Laclede Gas believes that the complaint lacks merit and is vigorously opposing it.

On July 9, 2008, Laclede Gas made a tariff filing with the MoPSC that would make the payment provisions for the restoration of gas service under the Utility’s Cold Weather Rule available to customers in the summer of 2008 and enable the Utility to increase or decrease its PGA rates to correct for any shortfall or surplus created by the difference between the gas cost portion of the Utility’s actual net bad debt write-offs and the amount of such cost that is embedded in its existing rates. As a result of the ensuing procedural schedule, the Cold Weather Rule portion of the filing became moot. On April 15, 2009, the Commission rejected the Utility’s tariffs on the grounds that it did not have the legal authority to approve them. On appeal, the Cole County Circuit Court reversed the Commission’s Order, but that Court’s decision was likewise reversed by the Western District of the Missouri Court of Appeals. Laclede’s application to the Missouri Supreme Court was denied on January 25, 2011.

On November 9, 2011, the Utility made an ISRS filing with the Commission designed to increase revenues by $2.0 million annually, essentially all of which was approved by the MoPSC effective January 13, 2012.

On June 29, 2010, the Office of Federal Contract Compliance Programs issued a Notice of Violations to Laclede Gas alleging lapses in certain employment selection procedures during a two-year period ending in February 2006. The Company believes that the allegations lack merit and is vigorously defending its position. Management, after discussion with counsel, believes that the final outcome of these matters will not have a material effect on the consolidated financial position and results of operations of the Company.




C RITICAL 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 GAAP. GAAP requires 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. Our critical accounting policies used in the preparation of our Consolidated Financial Statements are described in Item 7 of our Annual Report on Form 10-K for the fiscal year ended September 30, 2011 and include the following:

 
Accounts receivable and allowance for doubtful accounts
 
Employee benefits and postretirement obligations
 
Regulated operations
 
Non-regulated gas marketing energy contracts

There were no significant changes to these critical accounting policies during the three months ended December 31, 2011. For discussion of other significant accounting policies, see Note 1 of the Notes to Consolidated Financial Statements included in the Company’s Form 10-K for the fiscal year ended September 30, 2011.


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 of the Notes to Consolidated Financial Statements.

The Company continues to monitor the developments of the Financial Accounting Standards Board (FASB) relative to possible changes in accounting standards. Currently, the FASB is considering various changes to U. S. GAAP, some of which may be significant, as part of a joint effort with the International Accounting Standards Board to converge accounting standards. Future developments, depending on the outcome, have the potential to impact the Company’s financial condition and results of operations.


FINANCIAL CONDITION


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 (including cash payments for margin deposits associated with the Utility’s use of natural gas derivative instruments), variations in the timing of collections of gas cost under the Utility’s PGA Clause, and the utilization of storage gas inventories cause short-term cash requirements to vary during the year and from year to year, and can cause significant variations in the Utility’s cash provided by or used in operating activities.

Net cash used in operating activities was $50.1 million for the three months ended December 31, 2011, compared with net cash provided operating activities of $5.8 million for the three months ended December 31, 2010. The variation is primarily attributable to increased cash payments for margin deposits associated with the Utility’s use of natural gas derivative instruments and other variations associated with the timing of collections of gas cost under the Utility’s PGA Clause, as well as increased cash payments for the funding of pension plans.

 
 
 
 
Net cash used in investing activities for the three months ended December 31, 2011 was $18.6 million compared with $14.6 million for the three months ended December 31, 2010. Cash used in investing activities primarily reflected capital expenditures in both periods.
 
Net cash provided by financing activities was $70.0 million for the three months ended December 31, 2011 compared with net cash used in financing activities of $53.0 million for the three months ended December 31, 2010. The variation primarily reflects the increased issuance of short-term debt this year and the effect of the maturity of long-term debt last year.


L IQUIDITY AND CAPITAL RESOURCES

Cash and Cash Equivalents

Laclede Group had temporary cash investments totaling $19.8 million at December 31, 2011, earning an average interest rate of 0.2%. These investments, which are presented in the Cash and cash equivalents line of the Consolidated Balance Sheets, were diversified among money market funds and interest-bearing deposits at highly-rated commercial banks. The money market funds are accessible by the Company on demand. The bank deposits are also generally available on demand, though the banks reserve the right to require seven days’ notice for a withdrawal. These funds are used to support the working capital needs of the Company’s subsidiaries. The balance of short-term investments was stable during the three months ended December 31, 2011. Due to lower yields available to Laclede Group on its short-term investments, Laclede Group elected to provide a portion of Laclede Gas’ short-term funding through intercompany lending during the three months ended December 31, 2011.

Short-term Debt

As indicated in the discussion of cash flows above, the Company’s short-term borrowing requirements typically peak during the colder months. These short-term cash requirements can be met through the sale of commercial paper supported by lines of credit with banks or through direct use of the lines of credit. At December 31, 2011, Laclede Gas had a syndicated line of credit in place of $300 million from seven banks, with the largest portion provided by a single bank being 17.9%. This line is scheduled to expire in July 2016. Laclede Gas’ line of credit includes a covenant limiting total debt, including short-term debt, to no more than 70% of total capitalization. On December 31, 2011, total debt was 55% of total capitalization .

Short-term cash requirements outside of Laclede Gas have generally been met with internally-generated funds. However, Laclede Group has $50 million in a syndicated line of credit, scheduled to expire in July 2016, to meet short-term liquidity needs of its subsidiaries. The line of credit has a covenant limiting the total debt of the consolidated Laclede Group to no more than 70% of the Company’s total capitalization. This ratio stood at 45% on December 31, 2011. Laclede Group’s lines have been used to provide for seasonal funding needs. There were no borrowings under Laclede Group’s line during the three months ended December 31, 2011.

Information about Laclede Group’s consolidated short-term borrowings (excluding intercompany borrowings) during the three months ended December 31, 2011 and as of December 31, 2011, is presented below:

 
Laclede Gas Commercial Paper Borrowings
   
Three Months Ended December 31, 2011
 
   Weighted average borrowings outstanding
$81.2 million
   Weighted average interest rate
0.3%
   Range of borrowings outstanding
$40.0 – $133.5 million
   
As of December 31, 2011
 
   Borrowings outstanding at end of period
$113.0 million
   Weighted average interest rate
0.3%

Based on average short-term borrowings for the three months ended December 31, 2011, an increase in the average interest rate of 100 basis points would decrease Laclede Group’s pre-tax earnings and cash flows by approximately $0.8 million on an annual basis, portions of which may be offset through the application of PGA carrying costs.
 
 

 
Long-term Debt, Equity, and Shelf Registrations

The Utility has MoPSC authority to issue debt securities and preferred stock, including on a private placement basis, as well as to issue common stock, receive paid-in capital, and enter into capital lease agreements, all for a total of up to $518 million, effective through June 30, 2013. During the three months ended December 31, 2011, pursuant to this authority, the Utility sold 11 shares of its common stock to Laclede Group for $0.4 million. As of January 27, 2012, $515.3 million remains available under this authorization. The amount, timing, and type of additional financing to be issued will depend on cash requirements and market conditions, as well as future MoPSC authorizations.

At December 31, 2011, Laclede Gas had fixed-rate long-term debt totaling $365 million (including current maturities). While these long-term debt issues are fixed-rate, they are subject to changes in their 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. Under GAAP applicable to Laclede Gas’ regulated operations, losses or gains on early redemptions of long-term debt would typically be deferred as regulatory assets or regulatory liabilities and amortized over a future period. Of the Utility’s $365 million in long-term debt, $50 million have no call option, $235 million have make-whole call options, and $80 million are callable at par in 2013. None of the debt has any put options.

Laclede Group has a registration statement on file on Form S-3 for the issuance and sale of up to 285,222 shares of its common stock under its Dividend Reinvestment and Stock Purchase Program. There were 274,207 and 265,903 shares at December 31, 2011 and January 27, 2012, respectively, remaining available for issuance under its Form S-3. Laclede Group also has an automatic shelf registration statement on Form S-3 for the issuance of equity and debt securities. No securities have been issued under that S-3. The amount, timing, and type of financing to be issued under this shelf registration will depend on cash requirements and market conditions.

Guarantees

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 into 2015. At December 31, 2011, the maximum guarantees under these leases were $0.9 million. However, the Utility believes it is unlikely that it will be subject to the maximum payment amount because it estimates that the residual value of the leased vehicles will be adequate to satisfy most of the guaranteed amounts. At December 31, 2011, the carrying value of the liability recognized for these guarantees was $0.2 million.

Laclede Group had guarantees totaling $96.3 million for performance and payment of certain wholesale gas supply purchases by LER, as of December 31, 2011. Since that date, total guarantees issued by Laclede Group on behalf of LER increased by $1.0 million, bringing the total to $97.3 million in guarantees outstanding at January 27, 2012. No amounts have been recorded for these guarantees in the financial statements.

Other

The Company’s and the Utility’s access to capital markets, including the commercial paper market, and their respective financing costs, may depend on the credit rating of the entity that is accessing the capital markets. The credit ratings of the Company and the Utility remain at investment grade, but are subject to review and change by the rating agencies.

Utility capital expenditures were $18.3 million for the three months ended December 31, 2011, compared with $15.5 million for the same period last year. The increase in capital expenditures, compared with the prior period, is primarily attributable to additional expenditures for distribution plant and information technology investments. During fiscal 2011, Laclede Gas began a multi-year project to enhance its technology, customer service, and business processes by replacing its existing work management, financial, and supply chain software applications. There were essentially no non-utility capital expenditures during the three months ended December 31, 2011. Non-utility capital expenditures were $0.1 million for the same period last year.

Consolidated capitalization at December 31, 2011 consisted of 63.5% Laclede Group common stock equity and 36.5% 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, which primarily include capital expenditures, scheduled maturities of long-term debt, short-term seasonal needs, and dividends.
 
The seasonal nature of Laclede Gas’ sales affects the comparison of certain balance sheet items at December 31, 2011 and at September 30, 2011, such as Accounts receivable - net, Gas stored underground, Notes payable, Accounts payable, Regulatory assets and Regulatory liabilities, and Advance customer billings. The Consolidated Balance Sheet at December 31, 2010 is presented to facilitate comparison of these items with the corresponding interim period of the preceding fiscal year.

CONTRACTUAL OBLIGATIONS

As of December 31, 2011, 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
2012
 
Fiscal Years
2013-2014
 
Fiscal Years
2015-2016
 
2017 and
thereafter
 
Principal Payments on Long-Term Debt
 
$
365.0
 
$
 
$
25.0
 
$
 
$
340.0
 
Interest Payments on Long-Term Debt
   
452.1
   
13.9
   
43.5
   
42.7
   
352.0
 
Capital Leases (a)
   
0.3
   
0.1
   
0.1
   
0.1
   
 
Operating Leases (a)
   
10.5
   
3.4
   
6.3
   
0.8
   
 
Purchase Obligations – Natural Gas (b)
   
496.4
   
318.4
   
155.2
   
15.4
   
7.4
 
Purchase Obligations – Other (c)
   
92.0
   
28.4
   
23.3
   
18.4
   
21.9
 
Total (d)
 
$
1,416.3
 
$
364.2
 
$
253.4
 
$
77.4
 
$
721.3
 

      (a)
Lease obligations are primarily for office space, office equipment, vehicles, and power operated equipment in the Regulated Gas Distribution segment. 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 in the Regulated 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 December 31, 2011 forward market prices. Laclede Gas recovers the costs related to its purchases, transportation, and storage of natural gas through the operation of its PGA Clause, subject to prudence review by the MoPSC; 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 primarily reflect miscellaneous agreements for the purchase of materials and the procurement of services necessary for normal operations.
      (d)
The category of Other Long-Term Liabilities has been excluded from the table above because there are no material amounts of contractual obligations under this category. Long-term liabilities associated with unrecognized tax benefits, totaling $5.7 million, have been excluded from the table above because the timing of future cash outflows, if any, cannot be reasonably estimated. Also, commitments related to pension and postretirement benefit plans have been excluded from the table above. At this writing, the Company expects to make contributions to its qualified, trusteed pension plans of at least $15.7 million during the remaining nine months of fiscal year 2012. Laclede Gas anticipates a $6.6 million contribution relative to its non-qualified pension plans during the remaining nine months of fiscal year 2012. With regard to the postretirement benefits, the Company anticipates Laclede Gas will contribute $11.9 million to the qualified trusts and $0.3 million directly to participants from Laclede Gas’ funds during the remaining nine months of fiscal year 2012. For further discussion of the Company’s pension and postretirement benefit plans, refer to Note 2 , Pension Plans and Other Postretirement Benefits, of the Notes to Consolidated Financial Statements.



M ARKET RISK

Commodity Price Risk

Laclede Gas’ commodity price risk, which arises from market fluctuations in the price of natural gas, is primarily managed through the operation of its PGA Clause. The PGA Clause allows Laclede Gas to flow through to customers, subject to prudence review by the MoPSC, the cost of purchased gas supplies. The Utility is allowed the flexibility to make up to three discretionary PGA changes during each year, in addition to its mandatory November PGA change, so long as such changes are separated by at least two months. The Utility is able to mitigate, to some extent, changes in commodity prices through the use of physical storage supplies and regional supply diversity. Laclede Gas also has a risk management policy that allows for the purchase of natural gas derivative instruments with the goal of managing its 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 derivative instruments are allowed to be passed on to the Utility’s customers through the operation of its PGA Clause. Accordingly, Laclede Gas does not expect any adverse earnings impact as a result of the use of these derivative instruments. However, the timing of recovery for cash payments related to margin requirements may cause short-term cash requirements to vary. Nevertheless, carrying costs associated with such requirements, as well as other variations in the timing of collections of gas costs, are recovered through the PGA Clause. For more information about the Utility’s natural gas derivative instruments, see Note 7 , Derivative Instruments and Hedging Activities, of the Notes to Consolidated Financial Statements.

In the course of its business, Laclede Group’s non-regulated gas marketing subsidiary, LER, enters into contracts to purchase and sell natural gas at fixed prices and natural gas index-based prices. Commodity price risk associated with these contracts has the potential to impact earnings and cash flows. To minimize this risk, LER has a risk management policy that provides for daily monitoring of a number of business measures, including fixed price commitments. In accordance with the risk management policy, LER manages the price risk associated with its fixed-price commitments. This risk is currently managed either by closely matching the offsetting physical purchase or sale of natural gas at fixed-prices or through the use of natural gas futures and swap contracts traded on or cleared through the NYMEX and ICE to lock in margins. At December 31, 2011, LER’s unmatched fixed-price positions were not material to Laclede Group’s financial position or results of operations.

As mentioned above, LER uses natural gas futures and swap contracts traded on or cleared through the NYMEX and ICE to manage the commodity price risk associated with its fixed-price natural gas purchase and sale commitments. These derivative instruments are generally designated as cash flow hedges of forecasted purchases or sales. Such accounting treatment generally permits a substantial portion of the gain or loss to be deferred from recognition in earnings until the period that the associated forecasted purchase or sale is recognized in earnings. To the extent a hedge is effective, gains or losses on the derivatives will be offset by changes in the value of the hedged forecasted transactions. Accordingly, the Company does not expect any material earnings impact associated with the use of these instruments. Information about the fair values of LER’s exchange-traded/cleared natural gas derivative instruments is presented below:

(Thousands)
 
Derivative
Fair
Values
 
Cash
Margin
 
Derivatives
and Cash
Margin
 
                     
Net balance of derivative assets at September 30, 2011
 
$
209
 
$
1,100
 
$
1,309
 
Changes in fair value
   
2,981
   
   
2,981
 
Settlements
   
(1,689
)
 
   
(1,689
)
Changes in cash margin
   
   
(851
)
 
(851
)
Net balance of derivative assets at December 31, 2011
 
$
1,501
 
$
249
 
$
1,750
 




   
At December 31, 2011
 
   
Maturity by Fiscal Year
 
(Thousands)
   
Total
   
2012
   
2013
   
2014
 
Fair values of exchange-traded/cleared natural gas derivatives - net
 
$
1,501
 
$
1,390
 
$
130
 
$
(19
)
                           
MMBtu – net long (short) futures/swap positions
   
(2,600
)
 
(2,110
)
 
(553
)
 
63
 

Many of LER’s physical natural gas derivative contracts are designated as normal purchases or normal sales, as permitted by GAAP. This election permits the Company to account for the contract in the period the natural gas is delivered. However, certain contracts do not qualify for this election under GAAP and are required to be accounted for as derivatives with changes in fair value recognized in earnings in the periods prior to physical delivery. Below is a reconciliation of the beginning and ending balances for physical natural gas contracts accounted for as derivatives, none of which will settle beyond fiscal year 2013:

(Thousands)
     
         
Net balance of derivative assets at September 30, 2011
 
$
1,923
 
Changes in fair value
   
(80
)
Settlements
   
238
 
Net balance of derivative assets at December 31, 2011
 
$
2,081
 

For further details related to LER’s derivatives and hedging activities, see Note 7 , Derivative Instruments and Hedging Activities, of the Notes to Consolidated Financial Statements.

Counterparty Credit Risk

LER has concentrations of counterparty credit risk in that a significant portion of its transactions are with (or are associated with) energy producers, utility companies, and pipelines. These concentrations of counterparties have the potential to affect the Company’s overall exposure to credit risk, either positively or negatively, in that each of these three groups may be affected similarly by changes in economic, industry, or other conditions. LER also has concentrations of credit risk with certain individually significant counterparties. To the extent possible, LER enters into netting arrangements with its counterparties to mitigate exposure to credit risk. Although not recorded on the consolidated balance sheets, LER is also exposed to credit risk associated with its derivative contracts designated as normal purchases and normal sales. LER closely monitors its credit exposure and, although uncollectible amounts have not been significant, increased counterparty defaults are possible and may result in financial losses and/or capital limitations. For more information on these concentrations of credit risk, including how LER manages these risks, see Note 8 , Concentrations of Credit Risk, of the Notes to Consolidated Financial Statements.

Interest Rate Risk

The Company is subject to interest rate risk associated with its long-term and short-term debt issuances. Based on average short-term borrowings during the three months ended December 31, 2011, an increase of 100 basis points in the underlying average interest rate for short-term debt would have caused an increase in interest expense of approximately $0.8 million on an annual basis. Portions of such increases may be offset through the application of PGA carrying costs. At December 31, 2011, Laclede Gas had fixed-rate long-term debt totaling $365 million (including current maturities). 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. Under GAAP applicable to Laclede Gas’ regulated operations, losses or gains on early redemptions of long-term debt would typically be deferred as regulatory assets or regulatory liabilities and amortized over a future period.




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 11 , Commitments and Contingencies, of the Notes to Consolidated Financial Statements.


OFF-BALANCE SHEET ARRANGEMENTS

Laclede Group has no off-balance sheet arrangements.


Item 3 . Quantitative and Qualitative Disclosures About Market Risk

For this discussion, see Part I., Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations – Market Risk , on page 41 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 first fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.






PART II . OTHER INFORMATION

Item 1 . Legal Proceedings

For a description of environmental matters and legal proceedings, see Note 11 , Commitments and Contingencies, of the Notes to Consolidated Financial Statements. For a description of pending regulatory matters of Laclede Gas, see Part I., Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations - Regulatory and Other Matters , on page 36 of this report.

Laclede Group and its subsidiaries are involved in litigation, claims and investigations arising in the normal course of business. Management, after discussion with counsel, believes that the final outcome of these matters will not have a material effect on the consolidated financial position or results of operations of the Company.

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

During the quarter ended December 31, 2011, the only repurchases of our common stock were pursuant to elections by employees to have shares of stock withheld to cover employee tax withholding obligations upon the vesting of performance-based and time-vested restricted stock and stock units. The following table provides information on those repurchases.

 
 
 
Period
 
 
Total No. of
Shares Purchased
 
 
Average Price Paid
Per Share
Total No. of Shares
Purchased as Part of
Publicly Announced
Plans
Maximum No. of
Shares that May
Yet be Purchased
Under the Plans
October 1, 2011 –
October 31, 2011
 
 
 
 
November 1, 2011 –
November 30, 2011
 
22,790
 
$40.03
 
 
December 1, 2011 –
December 31, 2011
 
6,367
 
$39.72
 
 
Total
29,157


Item 6 . Exhibits

(a)












SIGNATURE
 
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.
 
     
The Laclede Group, Inc.
       
Dated:
 
January 27, 2012
 
By: 
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Chief Financial Officer
         
(Authorized Signatory and Chief Financial Officer)











INDEX TO EXHIBITS


Exhibit No.
   
     
-
Form of Performance Contingent Restricted Stock Unit Award Agreement
     
-
Ratio of Earnings to Fixed Charges.
     
-
CEO and CFO Certifications under Exchange Act Rule 13a – 14(a).
     
-
CEO and CFO Section 1350 Certifications.
     




 
47
 
 


Exhibit 10.1
The Laclede Group
 
2006 Equity Incentive Plan
Performance Contingent
Stock Unit Award Agreement
 
THIS AGREEMENT, made as of the __ day of __________ 20__, between The Laclede Group, Inc. (“Company”) and _________________ (“Participant”).
 
Pursuant to the terms of the Company’s 2006 Equity Incentive Plan as approved by shareholders in January 2011 (“Plan”), the Participant has been awarded _____ performance contingent stock units subject to the terms and conditions of the Plan and this Award Agreement (“Units”).  This number represents the High Performance level of achievement and is the maximum number of Units that can be earned under this Award Agreement.

NOW, THEREFORE, in consideration of the mutual covenants set forth in this Agreement, the parties hereto hereby agree as follows:
 
 
1.
Performance Contingent Stock Unit Award .  Subject to the potential reduction as set forth in Section 5, and further subject to the other terms and conditions of this Agreement, the Units will become non-forfeitable (“Vested”) on __________ , 20__ (Vesting Date), provided that (i) the Compensation Committee of the Company’s Board of Directors (“Committee”) has certified that the Company has achieved Dividend Related Earnings (as defined in Appendix A) for the performance period from October 1, 20__ through September 30, 20__ (“Performance Period”) and (ii) the Participant is continuously employed by the Company until the Vesting Date.

 
(a)
Dividend Equivalents .  Any cash dividends declared before the Vesting Date on the shares of common stock underlying the Units (“Shares”) shall not be paid currently but shall be accumulated during the Performance Period for such Units (“Dividend Equivalents”) and become payable, if at all, on the Vesting Date.  If all or a portion of the Units and shares of common stock underlying such Units are forfeited, the Dividend Equivalents relating to such forfeited Units and Shares shall also be forfeited.  Dividend Equivalents shall be paid as provided below in Section 5 and shall not accrue any earnings or interest during the Performance Period.

 
2.
Award Date .  The Award Date of the Units awarded under this Agreement is ___________ , 20 __.

 
1
 
 


 
 
3.
Incorporation of Plan .  All terms, conditions and restrictions of the Plan are incorporated herein and made a 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 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 .  Except as otherwise provided in this Agreement, Participant shall forfeit any and all right to the Units and related Dividend Equivalents if the Participant is terminated with or without cause or the Participant voluntarily terminates employment with the Company and its subsidiaries prior to the Vesting Date.
 
 
5.
Lapse of Restrictions .  The Participant accepts the award under this Agreement (“Award”) and agrees that the restrictions relative to such Award shall lapse only following the conclusion of the Performance Period and only to the extent that there are Dividend Related Earnings certified by the Committee.  If there are no Dividend Related Earnings, the Units and related Dividend Equivalents shall be forfeited.
 
The actual number of Units that vest after achieving Dividend Related Earnings during the Performance Period may be reduced by the Committee in its sole and absolute discretion based on such factors as the Committee determines to be appropriate and/or advisable including, without limitation, the Company’s achievement relative to the metrics set forth in Appendix A to this Agreement for the Performance Period (“Performance Metrics Formula”).  It is the intention of the Committee that the Committee will exercise its discretion to reduce the number of Units that will vest based on the Performance Metrics Formula, provided that the Committee reserves the right to deviate from the Performance Metrics Formula and may reduce the number of Units that will vest based on such other factors as the Committee in its sole and absolute discretion determines to be appropriate and/or advisable; provided, however, that it is the intention of the Committee that it will deviate from the Performance Metrics Formula only in extreme and unusual circumstances.

Any Dividend Equivalents that the Committee certifies are earned relative to the Units will be paid to the Participant in no event later than March 15 of the calendar year following the end of the Performance Period.  Any Shares underlying the Units that the Committee certifies are earned will be issued and delivered to the Participant in no event later than March 15 of the calendar year following the end of the Performance Period.
 

 
2
 
 
 
Notwithstanding the foregoing,
 
 
(A)
In the event of a Change in Control, two-thirds of the Units and related Dividend Equivalents shall be deemed earned and prorated based on the number of months in the Performance Period to the date of the Change in Control, and the shares relative to such Units shall be issued and related Dividend Equivalents payable within 30 days following such Change in Control if :
 
                           (i) the Award has not otherwise been forfeited and
 
(ii) the successor or surviving corporation (or parent thereof) does not assume this Award or replace it with a comparable award, provided further that if the Award is assumed or replaced, such assumed or replaced Award shall provide that the restrictions shall lapse if Participant is involuntarily terminated without Cause within 24 months of the Change in Control (a “Change in Control Termination”);
 
 
(B)
If a Participant leaves the employment of the Company and its subsidiaries due to death, disability or retirement (including early retirement and disability retirement) prior to the end of the Performance Period, the Participant will be eligible to earn a prorated Award (including Dividend Equivalents), as the Administrator in its sole discretion may determine, based on the number of full months as a Participant during the Performance Period and will be eligible to receive the Shares (and related Dividend Equivalents) to the extent certified by the Committee as provided in Section 5 above.
 
 
6.
How Dividend Equivalents Held .   Dividend Equivalents are intended to constitute an "unfunded" obligation of the Company and nothing in the Plan or this Agreement shall give the Participant any rights that are greater than those of a general unsecured creditor of the Company. All amounts accumulated on the Participants's behalf under this Agreement shall continue for all purposes to be part of the general assets of the Company Shares underlying the Units, when earned, shall be issued and delivered as provided in Section 5.
 
 
7.
Units Non-Transferable .  The Units (and any related Dividend Equivalents) 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 Shares underlying the Units have been issued and delivered to the Participant.
 

 
3
 
 
 
 
 
8.
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.
 
 
9.
Tax Withholding and Tax Election .  The Company shall not be obligated to deliver any Shares underlying the Units until Participant pays to the Company in cash, or any other form of property acceptable to the Company, the amount required to be withheld for any federal, state or local income, FICA or other taxes of any kind with respect to such shares.  The Participant may, by notice to the Company, elect to have such withholding satisfied by a reduction of the number of whole Shares otherwise so deliverable, such reduction to be calculated based on the Fair Market Value of the Shares on the Vesting Date.  The value of Shares withheld will not exceed the minimum amount of tax required to be withheld by law.  The Company and its subsidiaries shall, to the extent permitted by law, have the right to deduct such taxes, from any payment of any kind otherwise due to Participant.  Dividend Equivalents that become payable as provided in this Agreement shall be subject to tax withholdings in accordance with tax laws then in effect.
 
 
10.
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 underlying the Units that vest and are issued to Participant under this Agreement if, during the period beginning on the date hereof and ending 18 months following the date the Participant’s employment with the Company and its subsidiaries terminates (provided that such termination is other than a Change in Control Termination), the Participant: (1) discloses Confidential Information, as defined below, to any person not employed by the Company or any of its subsidiaries or not engaged to render services to the Company or any of its subsidiaries; or (2) Solicits Employees, as defined below.  Fair Market Value shall be calculated on the date of the first violation of this Section 10.
 

 
4
 
 

For purposes of this Section 10, “Confidential Information” means information concerning the Company, its subsidiaries and their 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 other than by his or her disclosure of such information 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 of, solicit to hire, or attempt to induce (or Participant’s assisting of any third party to hire, solicit 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.
 
 
11.
Integration.   This Agreement, and the other documents referred to herein or delivered pursuant hereto which form a part hereof, contains 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.
 
 
12.
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.
 
 
13.
Compliance with Laws and Regulations .   The obligations of the Company under this Agreement 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.
 

 
5
 
 
 
 
14.
Participant Acknowledgment .  By accepting the award under this Agreement, the Participant acknowledges receipt of a copy of the Plan, and acknowledges that all decisions, determinations and interpretations of the 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 10 of this Agreement will obligate the Participant to pay to the Company the Fair Market Value of the Shares underlying the Units that become vested or are issued pursuant to Section 5.
 

The Laclede Group, Inc.
 
By:
 
   
Title:
 
   
 
 
 
[Participant]

 
6
 
 


 
Appendix A to Performance Contingent Stock Unit Award
 
Performance Period .  The Performance Period begins October 1, 20__ and ends September 30, 20__.
 
Dividend Related Earnings .  Dividend Related Earnings means average Earnings Per Share over the Performance Period in excess of the annualized declared dividend per share for the Common Stock as of the Award Date.
 
Earnings Per Share .  For purposes of this Agreement, Earnings Per Share means net economic earnings per share as reported in the Company’s periodic reports filed with the Securities and Exchanges Commission reporting the results for quarterly and annual periods in the Performance Period.  The number of shares of Common Stock used in calculating Earnings Per Share will be consistent with that number used to calculate the Company’s basic earnings per share in its periodic reports.
 
Performance Metrics .  The Performance Metrics Formula for this Award that the Committee will use to exercise its discretion to reduce the number of Units that will Vest upon the Company’s achievement of Dividend Related Earnings include three performance metrics:  Average Earnings Per Share (__% weighting), Portfolio Development (__% weighting), and Relative Total Shareholder Return (__% weighting) as described in more detail below:
 
Metric 1 – Average Earnings Per Share – Achieve Company average Earnings Per Share over the Performance Period as specified below.
 
 
Threshold
Target
High Performance
Level of Performance
$_.__share
$_.__/share
$_.__/share
Units earned
[1/3 of Units times __%]
[2/3 of Units times __%]
[Units times __%]
 
Metric 2 – Portfolio Development – Aggregate development of/investment in new business as follows.
 
 
Threshold
Target
High Performance
Level of Performance
Investment of $___ million or added earnings of $.__/share
Investment of $___ million or added earnings of $.__/share
Investment of $___ million or added earnings of
$.__/share
Units earned
[1/3 of Units times __%]
[2/3 of Units times __%]
[Units times __%]
 

 
 

 

 
1
 
 

 

 
 
Metric 3 – Relative Total Shareholder Return (TSR) – Achieve level of TSR relative to established comparator group using average stock price for last quarter of fiscal year 20__ and average stock price for last quarter of fiscal year 20__, plus the value of reinvested dividends as provided below.
 
 
Threshold
Target
High Performance
Level of Performance
TSR ≥ 25 th percentile of peers
TSR ≥ 50 th percentile of peers
TSR ≥ 75 th percentile of peers
Units earned
[1/3 of Units times __%]
[2/3 of Units times __%]
[Units times __%]

 
Performance Metrics Formula .
 
o  
If performance on each of the Performance Metrics is below threshold, then no Units shall vest, and all Units and related Dividend Equivalents shall be forfeited.
 
o  
If performance on one or more of the Performance Metrics is achieved at or above Threshold, the number of Units that vest (and the amount of Dividend Equivalents that shall be payable) will equal the aggregate of Units earned under each Performance Metric.
 
o  
If performance on one or more of the Performance Metrics has been achieved between the Threshold and Target or Target and High Performance levels of performance, the Administrator shall interpolate for performance between the applicable levels and shall determine the number of Units that shall vest (and the amount of Dividend Equivalents that shall be payable).
 
Because the Company cannot issue fractional shares, the Administrator will round down to the nearest whole number of Units in all calculations.
 

 
2
 
 


Exhibit 12

THE LACLEDE GROUP, INC. AND SUBSIDIARY COMPANIES
 
SCHEDULE OF COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES
 

     
   
Twelve Months Ended
   
Dec. 31,
     
September 30,
(Thousands of Dollars)
   
2011
       
2011
   
2010
   
2009
   
2008
   
2007
                                         
Income from continuing
     operations before interest
                                       
     charges and income taxes
 
$
120,872
     
$
118,424
 
$
107,986
 
$
126,517
 
$
113,228
 
$
101,867
Add: One third of applicable
                                       
     rentals charged to operating
                                       
     expense (which approximates
                                       
     the interest factor)
   
1,749
       
1,799
   
1,825
   
1,833
   
1,691
   
1,485
         Total Earnings
 
$
122,621
     
$
120,223
 
$
109,811
 
$
128,350
 
$
114,919
 
$
103,352
                                         
                                         
Interest on long-term debt –
                                       
     Laclede Gas
 
$
22,957
     
$
23,161
 
$
24,583
 
$
24,583
 
$
19,851
 
$
22,502
Other interest
   
2,087
       
2,256
   
2,269
   
5,163
   
9,626
   
11,432
Add: One third of applicable
                                       
     rentals charged to operating
                                       
     expense (which approximates
                                       
     the interest factor)
   
1,749
       
1,799
   
1,825
   
1,833
   
1,691
   
1,485
          Total Fixed Charges
 
$
26,793
     
$
27,216
 
$
28,677
 
$
31,579
 
$
31,168
 
$
35,419
                                         
                                         
Ratio of Earnings to Fixed
                                       
     Charges
   
4.58
       
4.42
   
3.83
   
4.06
   
3.69
   
2.92
                                         
                                         
                                         



 
 
 
 


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 (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
       
5.
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
       
   
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
       
   
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 Date:
 
January 27, 2012
Signature:
 
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board
         
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 (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and
       
5.
The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):
       
   
a)
All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and
       
   
b)
Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

 Date:
 
January 27, 2012
Signature:
 
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Chief Financial Officer
 
 

 
 
 
 



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 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 December 31, 2011 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 December 31, 2011 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.



Date:
 
January 27, 2012
   
/s/ Douglas H. Yaeger
         
Douglas H. Yaeger
         
Chairman of the Board
         
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 December 31, 2011 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 December 31, 2011 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.


Date:
 
January 27, 2012
   
/s/ Mark D. Waltermire
         
Mark D. Waltermire
         
Chief Financial Officer