10-Q

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 March 31, 2013

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.

(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 April 26, 2013, there were 22,671,392 shares of the registrant’s Common Stock, par value $1.00 per share, outstanding.

TABLE OF CONTENTS			Page No.
PART I.  FINANCIAL INFORMATION
Item 1	Financial Statements:
		Statements of Consolidated Income	4
		Statements of Consolidated Comprehensive Income	5
		Consolidated Balance Sheets	6
		Statements of Consolidated Cash Flows	8
		Notes to Consolidated Financial Statements	9
Item 2	Management’s Discussion and Analysis of Financial Condition and
		Results of Operations	27
Item 3	Quantitative and Qualitative Disclosures About Market Risk		44
Item 4	Controls and Procedures		44
PART II.  OTHER INFORMATION
Item 1	Legal Proceedings		45
Item 1A	Risk Factors		45
Item 2	Unregistered Sales of Equity Securities and Use of Proceeds		47
Item 6	Exhibits		47
SIGNATURE			48
INDEX TO EXHIBITS			49

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 (SEC). 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, 2012.

3

Item 1. Financial Statements

THE LACLEDE GROUP, INC.

STATEMENTS OF CONSOLIDATED INCOME

(UNAUDITED)

	Three Months Ended				Six Months Ended
	March 31,				March 31,
(Thousands, Except Per Share Amounts)	2013		2012		2013		2012
Operating Revenues:
Gas Utility	$	354,097	$	298,620	$	604,208	$	549,522
Gas Marketing	41,255		59,434		96,504		218,022
Other	2,261		121		3,904		1,544
Total Operating Revenues	397,613		358,175		704,616		769,088
Operating Expenses:
Gas Utility
Natural and propane gas	230,440		171,164		366,956		317,915
Other operation expenses	35,267		38,043		69,187		75,608
Maintenance	5,924		5,761		11,655		11,069
Depreciation and amortization	11,258		10,175		22,223		20,264
Taxes, other than income taxes	21,751		20,093		36,557		34,760
Total Gas Utility Operating Expenses	304,640		245,236		506,578		459,616
Gas Marketing	35,995		61,805		93,376		214,364
Other	5,129		551		10,727		1,420
Total Operating Expenses	345,764		307,592		610,681		675,400
Operating Income	51,849		50,583		93,935		93,688
Other Income and (Income Deductions) – Net	1,340		1,381		2,424		3,320
Interest Charges:
Interest on long-term debt	5,689		5,740		11,127		11,479
Other interest charges	1,016		539		1,604		1,114
Total Interest Charges	6,705		6,279		12,731		12,593
Income Before Income Taxes	46,484		45,685		83,628		84,415
Income Tax Expense	16,242		16,001		27,818		29,557
Net Income	$	30,242	$	29,684	$	55,810	$	54,858
Weighted Average Number of Common Shares Outstanding:
Basic	22,421		22,254		22,396		22,223
Diluted	22,498		22,336		22,466		22,299
Basic Earnings Per Share of Common Stock	$	1.34	$	1.33	$	2.48	$	2.45
Diluted Earnings Per Share of Common Stock	$	1.34	$	1.32	$	2.47	$	2.45
Dividends Declared Per Share of Common Stock	$	0.425	$	0.415	$	0.850	$	0.830
See Notes to Consolidated Financial Statements.

4

THE LACLEDE GROUP, INC.

STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME

(UNAUDITED)

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2013			2012			2013			2012
Net Income	$	30,242		$	29,684		$	55,810		$	54,858
Other Comprehensive Income (Loss), Before Tax:
Net gains (losses) on cash flow hedging derivative instruments:
Net hedging (loss) gain arising during the period	(7,590		)	5,106			(6,201		)	8,153
Reclassification adjustment for (gains) losses included in
net income	(22		)	408			2,228			(2,422		)
Net unrealized gains (losses) on cash flow hedging
derivative instruments	(7,612		)	5,514			(3,973		)	5,731
Defined benefit pension and other postretirement plans:
Net actuarial loss arising during the period	—			(2,366		)	—			(2,366		)
Amortization of actuarial loss included in net periodic
pension and postretirement benefit cost	90			3,482			181			3,573
Net defined benefit pension and other postretirement plans	90			1,116			181			1,207
Other Comprehensive Income (Loss), Before Tax	(7,522		)	6,630			(3,792		)	6,938
Income Tax (Benefit) Expense Related to Items of Other
Comprehensive Income	(2,868		)	2,561			(1,417		)	2,680
Other Comprehensive (Loss) Income, Net of Tax	(4,654		)	4,069			(2,375		)	4,258
Comprehensive Income	$	25,588		$	33,753		$	53,435		$	59,116
See Notes to Consolidated Financial Statements.

5

THE LACLEDE GROUP, INC.

CONSOLIDATED BALANCE SHEETS

(UNAUDITED)

	Mar. 31,			Sept. 30,			Mar. 31,
(Thousands)	2013			2012			2012
ASSETS
Utility Plant	$	1,538,890		$	1,497,419		$	1,425,922
Less:  Accumulated depreciation and amortization	478,971			478,120			468,209
Net Utility Plant	1,059,919			1,019,299			957,713
Non-utility property	5,456			6,039			4,448
Other investments	52,910			50,775			54,688
Other Property and Investments	58,366			56,814			59,136
Current Assets:
Cash and cash equivalents	146,880			27,457			9,302
Accounts receivable:
Utility	148,624			64,027			100,015
Non-utility	55,925			51,042			34,915
Other	9,290			26,478			18,666
Allowance for doubtful accounts	(8,833		)	(7,705		)	(8,758		)
Delayed customer billings	19,663			—			13,464
Inventories:
Natural gas stored underground	32,776			92,729			57,456
Propane gas	8,963			10,200			8,964
Materials and supplies at average cost	4,385			3,543			4,102
Natural gas receivable	13,470			22,377			16,351
Derivative instrument assets	6,021			2,855			5,297
Unamortized purchased gas adjustments	11,039			40,674			11,241
Deferred income taxes	2,527			—			—
Prepayments and other	9,183			9,339			6,795
Total Current Assets	459,913			343,016			277,810
Deferred Charges:
Regulatory assets	424,743			456,047			457,749
Other	6,157			5,086			5,723
Total Deferred Charges	430,900			461,133			463,472
Total Assets	$	2,009,098		$	1,880,262		$	1,758,131

6

THE LACLEDE GROUP, INC.

CONSOLIDATED BALANCE SHEETS (Continued)

(UNAUDITED)

	Mar. 31,.			Sept. 30,.			Mar. 31,
(Thousands, except share amounts)	2013.			2012.			2012
CAPITALIZATION AND LIABILITIES
Capitalization:
Common stock (70,000,000 shares authorized, 22,643,693,     22,539,431, and 22,489,986 shares issued, respectively)	$	22,644		$	22,539		$	22,490
Paid-in capital	172,736			168,607			165,056
Retained earnings	451,114			414,581			425,500
Accumulated other comprehensive loss	(6,491		)	(4,116		)	2,158
Total Common Stock Equity	640,003			601,611			615,204
Long-term debt (less current portion)	464,434			339,416			339,386
Total Capitalization	1,104,437			941,027			954,590
Current Liabilities:
Notes payable	—			40,100			—
Accounts payable	108,648			89,503			73,045
Advance customer billings	—			25,146			—
Current portion of long-term debt	—			25,000			25,000
Wages and compensation accrued	16,175			13,908			13,873
Dividends payable	10,059			9,831			9,697
Customer deposits	7,706			8,565			9,459
Interest accrued	6,191			8,590			8,789
Taxes accrued	44,550			11,304			25,062
Deferred income taxes	—			6,675			6,615
Other	14,015			13,502			16,220
Total Current Liabilities	207,344			252,124			187,760
Deferred Credits and Other Liabilities:
Deferred income taxes	343,016			355,509			335,215
Unamortized investment tax credits	3,006			3,113			3,219
Pension and postretirement benefit costs	191,778			196,558			163,940
Asset retirement obligations	41,512			40,368			28,313
Regulatory liabilities	83,026			56,319			53,267
Other	34,979			35,244			31,827
Total Deferred Credits and Other Liabilities	697,317			687,111			615,781
Commitments and Contingencies (Note 11)
Total Capitalization and Liabilities	$	2,009,098		$	1,880,262		$	1,758,131
See Notes to Consolidated Financial Statements.

7

THE LACLEDE GROUP, INC.

STATEMENTS OF CONSOLIDATED CASH FLOWS

(UNAUDITED)

	Six Months Ended
	March 31,
(Thousands)	2013			2012
Operating Activities:
Net Income	$	55,810		$	54,858
Adjustments to reconcile net income to net cash provided by (used in)       operating activities:
Depreciation, amortization, and accretion	22,913			20,565
Deferred income taxes and investment tax credits	(11,132		)	6,167
Other – net	450			(744		)
Changes in assets and liabilities:
Accounts receivable – net	(71,164		)	(20,355		)
Unamortized purchased gas adjustments	29,635			14,478
Deferred purchased gas costs	43,827			(30,160		)
Accounts payable	23,797			(26,546		)
Delayed customer billings - net	(44,809		)	(28,694		)
Taxes accrued	32,971			12,575
Natural gas stored underground	59,953			57,714
Other assets and liabilities	115			11,601
Net cash provided by operating activities	142,366			71,459
Investing Activities:
Capital expenditures	(62,707		)	(40,658		)
Other investments	(2,126		)	(1,440		)
Net cash used in investing activities	(64,833		)	(42,098		)
Financing Activities:
Issuance of long-term debt	125,000			—
Maturity of first mortgage bonds	(25,000		)	—
Repayment of short-term debt – net	(40,100		)	(46,000		)
Changes in book overdrafts	(1,262		)	357
Issuance of common stock	2,852			2,195
Non-employee directors’ restricted stock awards	—			(565		)
Dividends paid	(19,054		)	(18,314		)
Employees’ taxes paid associated with restricted shares withheld upon vesting	(729		)	(1,165		)
Excess tax benefits from stock-based compensation	636			185
Other	(453		)	(29		)
Net cash provided by (used in) financing activities	41,890			(63,336		)
Net Increase (Decrease) in Cash and Cash Equivalents	119,423			(33,975		)
Cash and Cash Equivalents at Beginning of Period	27,457			43,277
Cash and Cash Equivalents at End of Period	$	146,880		$	9,302
Supplemental Disclosure of Cash Paid (Refunded) During the Period for:
Interest	$	14,569		$	12,521
Income taxes	(3,165		)	2,763
See Notes to Consolidated Financial Statements.

8

THE LACLEDE GROUP, INC.

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

(UNAUDITED)

1.        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 2012 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 flowsof 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. Laclede Energy Resources, Inc. (LER) includes its wholly owned subsidiary, LER Storage Services, Inc., which became operational on January 1, 2012.

REVENUE RECOGNITION - Laclede Gas reads meters and bills its customers on monthly cycles. The Utility records its gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at March 31, 2013 and 2012, for the Utility, were $33.3 million and $13.0 million, respectively. The amount of accrued unbilled revenue at September 30, 2012 was $11.6 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 Gas Utility Operating Revenues for the quarters ended March 31, 2013 and 2012 were $17.2 million and $15.5 million, respectively. Amounts recorded in Gas Utility Operating Revenues for the six months ended March 31, 2013 and 2012 were $27.5 million and $25.7 million, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.

NEW ACCOUNTING STANDARDS - In June 2011, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (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, did not impact total net income, comprehensive income, or earnings per share upon adoption in the first quarter of fiscal year 2013.

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.

In February 2013, the FASB issued ASU No. 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income.” This ASU amends Accounting Standards Codification (ASC) Topic 220, “Comprehensive Income,” by requiring entities to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to provide information on significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. The Company will present the new disclosures prospectively beginning in the first quarter of fiscal year 2014.

9

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 a growth segment consisting of exposure to equity markets, commodities, real estate and inflation-indexed securities, achieved through derivative instruments.

Pension costs for quarters ended March 31, 2013 and 2012 were $4.2 million and $7.6 million, respectively, including amounts charged to construction. Pension costs for six months ended March 31, 2013 and 2012 were $8.4 million and $11.8 million, respectively, including amounts charged to construction.

The net periodic pension costs include the following components:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2013			2012			2013			2012
Service cost – benefits earned during the period	$	2,311		$	2,301		$	4,622		$	4,613
Interest cost on projected benefit obligation	4,066			4,840			8,132			9,711
Expected return on plan assets	(4,741		)	(4,899		)	(9,482		)	(9,798		)
Amortization of prior service cost	136			148			272			296
Amortization of actuarial loss	2,839			2,259			5,678			4,536
Loss on lump-sum settlement	—			3,407			—			3,407
Sub-total	4,611			8,056			9,222			12,765
Regulatory adjustment	(433		)	(484		)	(867		)	(967		)
Net pension cost	$	4,178		$	7,572		$	8,355		$	11,798

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. There were no lump-sum payments recognized as settlements during the six months ended March 31, 2013. Lump-sum payments recognized as settlements were $6.4 million during the six months ended March 31, 2012.

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 $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 2013 contributions to the pension plans through March 31, 2013 were $8.9 million to the qualified trusts and approximately $0.3 million to the non-qualified plans. Contributions to the pension plans for the remaining six months of fiscal 2013 are anticipated to be at least $14.5 million to the qualified trusts and $0.8 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 both the quarters ended March 31, 2013 and 2012 were $2.4 million, including amounts charged to construction. Postretirement benefit costs for both the six months ended March 31, 2013 and 2012 were $4.8 million, including amounts charged to construction.

10

Net periodic postretirement benefit costs consisted of the following components:

	Three Months Ended March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013			2012
Service cost – benefits earned during the period	$	2,534		$	2,015		$	5,067		$	4,030
Interest cost on accumulated postretirement benefit obligation	1,279			1,380			2,558			2,760
Expected return on plan assets	(1,081		)	(991		)	(2,162		)	(1,982		)
Amortization of transition obligation	23			34			46			68
Amortization of prior service cost (credit)	1			(518		)	2			(1,036		)
Amortization of actuarial loss	1,325			1,065			2,650			2,130
Sub-total	4,081			2,985			8,161			5,970
Regulatory adjustment	(1,699		)	(604		)	(3,398		)	(1,208		)
Net postretirement benefit cost	$	2,382		$	2,381		$	4,763		$	4,762

Missouri state law provides for the recovery in rates of costs accrued pursuant to 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 $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 2013 contributions to the postretirement plans through March 31, 2013 were $4.1 million to the qualified trusts and approximately $0.4 million paid directly to participants from Laclede Gas' funds. Contributions to the postretirement plans for the remaining six months of fiscal year 2013 are anticipated to be $12.2 million to the qualified trusts and $0.4 million paid directly to participants from Laclede Gas’ funds.

3.        STOCK-BASED COMPENSATION

Awards of stock-based compensation are made pursuant to The Laclede Group 2006 Equity Incentive Plan (2006 Plan). Refer to Note 3 of the Consolidated Financial Statements included in the Company’s Form 10-K for the fiscal year ended September 30, 2012 for descriptions of the plan.

Restricted Stock Awards

During the six months ended March 31, 2013, the Company granted 108,419 performance-contingent restricted stock units to executive officers and key employees at a weighted average grant date fair value of $34.48 per share. This number represents the maximum shares that can be earned pursuant to the terms of the awards. Most of these stock units have a performance period ending September 30, 2015. While the participants have no interim voting rights on these stock units, dividends accrue during the performance period and are paid to the participants upon vesting, but are subject to forfeiture if the underlying stock units do not vest. The number of stock 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 GAAP.

11

Activity of restricted stock and restricted stock units subject to performance and/or market conditions during the six months ended March 31, 2013 is presented below:

	Restricted Stock/ Stock Units		Weighted Average Grant Date Fair Value
Nonvested at September 30, 2012	232,403		$	30.89
Granted (maximum shares that can be earned)	108,419		$	34.48
Vested	(37,436	)	$	27.02
Forfeited	(48,782	)	$	25.71
Nonvested at March 31, 2013	254,604		$	33.98

During the six months ended March 31, 2013, the Company granted 58,774 shares of time-vested restricted stock and stock units to executive officers, key employees, and directors at a weighted average grant date fair value of $39.96 per share. Most of these shares were awarded on December 3, 2012 and vest December 3, 2015. In the interim, participants receive full voting rights and dividends, which are not subject to forfeiture.

Time-vested restricted stock and stock unit activity for the six months ended March 31, 2013 is presented below:

	Restricted Stock/ Stock Units		Weighted Average Grant Date Fair Value
Nonvested at September 30, 2012	115,115		$	36.54
Granted	58,774		$	39.96
Vested	(20,200	)	$	30.46
Forfeited	(3,250	)	$	38.18
Nonvested at March 31, 2013	150,439		$	38.65

During the six months ended March 31, 2013, 57,636 shares of restricted stock and stock units (performance-contingent and time-vested), awarded on November 4, 2009, December 1, 2009, and January 4, 2010, vested. The Company withheld 18,744 of the vested shares at a weighted average price of $38.90 per share pursuant to elections by employees to satisfy tax withholding obligations.

Stock Option Awards

Stock option activity for the six months ended March 31, 2013 is presented below:

	Stock Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (Years)	Aggregate Intrinsic Value ($000)
Outstanding at September 30, 2012	214,000		$	31.02
Granted	—		$	—
Exercised	(49,500	)	$	29.54
Forfeited	—		$	—
Expired	—		$	—
Outstanding at March 31, 2013	164,500		$	31.47	2.1	$	1,848
Fully Vested and Expected to Vest at March 31, 2013	164,500		$	31.47	2.1	$	1,848
Exercisable at March 31, 2013	164,500		$	31.47	2.1	$	1,848

12

The closing price of the Company’s common stock was $42.70 at March 31, 2013.

Equity Compensation Costs

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

	Three Months Ended March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013			2012
Total equity compensation cost	$	1,137		$	684		$	1,759		$	1,351
Compensation cost capitalized	(356		)	(221		)	(539		)	(359		)
Compensation cost recognized in net income	781			463			1,220			992
Income tax benefit recognized in net income	(298		)	(179		)	(467		)	(383		)
Compensation cost recognized in net income, net of income tax	$	483		$	284		$	753		$	609

As of March 31, 2013, there was $7.1 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 2.2 years.

4.        EARNINGS PER COMMON SHARE

	Three Months Ended March 31,				Six Months Ended March 31,
(Thousands, Except Per Share Amounts)	2013		2012		2013		2012
Basic EPS:
Net Income	$	30,242	$	29,684	$	55,810	$	54,858
Less: Income allocated to participating securities	186		167		312		324
Net Income Available to Common Shareholders	$	30,056	$	29,517	$	55,498	$	54,534
Weighted Average Shares Outstanding	22,421		22,254		22,396		22,223
Earnings Per Share of Common Stock	$	1.34	$	1.33	$	2.48	$	2.45
Diluted EPS:
Net Income	$	30,242	$	29,684	$	55,810	$	54,858
Less: Income allocated to participating securities	186		166		311		323
Net Income Available to Common Shareholders	$	30,056	$	29,518	$	55,499	$	54,535
Weighted Average Shares Outstanding	22,421		22,254		22,396		22,223
Dilutive Effect of Stock Options, Restricted Stock,
and Restricted Stock Units	77		82		70		76
Weighted Average Diluted Shares	22,498		22,336		22,466		22,299
Earnings Per Share of Common Stock	$	1.34	$	1.32	$	2.47	$	2.45
Outstanding Shares Excluded from the
Calculation of Diluted EPS Attributable to:
Restricted stock and stock units subject to
performance and/or market conditions	211		203		211		203

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5.        FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis are as follows:

					Classification of Estimated Fair Value
(Thousands)	Carrying Amount		Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
As of March 31, 2013
Cash and cash equivalents	$	146,880	$	146,880	$	136,826	$	10,054	$	—
Short-term debt	—		—		—		—		—
Long-term debt, including current portion	464,434		539,260		—		539,260		—
As of September 30, 2012
Cash and cash equivalents	$	27,457	$	27,457	$	17,380	$	10,077	$	—
Short-term debt	40,100		40,100		—		40,100		—
Long-term debt, including current portion	364,416		452,768		—		452,768		—
As of March 31, 2012
Cash and cash equivalents	$	9,302	$	9,302	$	4,261	$	5,041	$	—
Short-term debt	—		—		—		—		—
Long-term debt, including current portion	364,386		432,098		—		432,098		—

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. Refer to Note 6, Fair Value Measurements, for information on financial instruments measured at fair value on a recurring basis.

14

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 March 31, 2013
Assets
U. S. Stock/Bond Mutual Funds	$	13,922	$	—	$	—	$	—		$	13,922
NYMEX/ICE natural gas contracts	11,010		379		—		(8,209		)	3,180
NYMEX gasoline and heating
oil contracts	322		—		—		(192		)	130
Natural gas commodity contracts	—		2,888		117		(289		)	2,716
Total	$	25,254	$	3,267	$	117	$	(8,690	)	$	19,948
Liabilities
NYMEX/ICE natural gas contracts	$	2,447	$	1,342	$	—	$	(3,789	)	$	—
Natural gas commodity contracts	—		990		24		(289		)	725
Interest rate swaps	$	—	$	4,549	$	—	$	—		$	4,549
Total	$	2,447	$	6,881	$	24	$	(4,078	)	$	5,274
As of September 30, 2012
Assets
U. S. Stock/Bond Mutual Funds	$	13,187	$	—	$	—	$	—		$	13,187
NYMEX/ICE natural gas contracts	7,411		994		—		(8,405		)	—
NYMEX gasoline and heating
oil contracts	344		—		—		(344		)	—
Natural gas commodity contracts	—		3,060		113		(299		)	2,874
Total	$	20,942	$	4,054	$	113	$	(9,048	)	$	16,061
Liabilities
NYMEX/ICE natural gas contracts	$	12,253	$	1,891	$	—	$	(14,144	)	$	—
Natural gas commodity contracts	—		428		4		(299		)	133
Total	$	12,253	$	2,319	$	4	$	(14,443	)	$	133
As of March 31, 2012
Assets
U. S. Stock/Bond Mutual Funds	$	17,907	$	—	$	—	$	—		$	17,907
NYMEX/ICE natural gas contracts	5,182		1,310		—		(4,881		)	1,611
NYMEX gasoline and heating
oil contracts	81		—		—		(81		)	—
Natural gas commodity contracts	—		4,362		79		(538		)	3,903
Total	$	23,170	$	5,672	$	79	$	(5,500	)	$	23,421
Liabilities
NYMEX/ICE natural gas contracts	$	37,811	$	2,342	$	—	$	(40,153	)	$	—
Natural gas commodity contracts	—		1,190		21		(538		)	673
Total	$	37,811	$	3,532	$	21	$	(40,691	)	$	673

15

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 March 31,					Six Months Ended March 31,
(Thousands)	2013		2012			2013			2012
Beginning of period	$	30	$	37		$	109		$	13
Settlements	37		(41		)	(29		)	(7		)
Net losses related to derivatives not held   at end of period	—		(1		)	—			(4		)
Net gains related to derivatives still held   at end of period	26		63			13			56
End of period	$	93	$	58		$	93		$	58

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 March 31, 2013, Laclede Gas held 0.5 million gallons of gasoline futures contracts at an average price of $2.30 per gallon. Most of these contracts, the longest of which extends to April 2014, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815. The gains or losses on these derivative instruments are not subject to the Utility’s PGA Clause.

16

In the course of its business, Laclede Group’s gas marketing subsidiary, LER, which includes its wholly owned subsidiary LER Storage Services, Inc., enters into commitments associated with the purchase or sale of natural gas. Certain 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 March 31, 2013, the fair values of 69.6 million MMBtu of non-exchange traded natural gas commodity contracts were reflected in the Consolidated Balance Sheet. Of these contracts, 59.8 million MMBtu will settle during fiscal year 2013, while the remaining 9.8 million MMBtu will settle during fiscal year 2014. 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 Clear Europe (ICE) futures, swap, and option contracts to lock in margins. At March 31, 2013, 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, swap, and option contracts used to lock in margins may be designated as cash flow hedges of forecasted transactions for financial reporting purposes.

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 March 31, 2013 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 2013	—	$	—	4.36	$	3.61
Fiscal 2014	—	—		3.26	3.86
Open long futures positions
Fiscal 2013	7.58	$	3.40	0.77	$	3.71
Fiscal 2014	4.87	3.97		0.65	3.01

At March 31, 2013, Laclede Gas and LER also had 14.2 million MMBtu and 1.5 million MMBtu, respectively, of other price mitigation in place through the use of NYMEX natural gas option-based strategies.

In February 2013, Laclede Group entered into certain interest rate swap agreements to effectively lock in interest rates on a portion of the long-term debt it anticipates issuing to finance its pending acquisition of Missouri Gas Energy (MGE). These derivative instruments have been designated as cash flow hedges of forecasted transactions. These forward starting swaps involve the payment of a fixed interest rate and the receipt of a floating interest rate (the London Interbank Offered Rate, also known as LIBOR) over the terms specified in the contracts. At March 31, 2013, the notional amount of interest rate swaps outstanding was $355 million with stated maturities ranging from 2018 to 2043 and fixed interest rates ranging between 1.28% and 3.14%.

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 March 31, 2013, it is expected that approximately $3.1 million of pre-tax unrealized losses 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.

17

The Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income
		Three Months Ended						Six Months Ended
	Location of Gain (Loss)	March 31,						March 31,
(Thousands)	Recorded in Income	2013			2012			2013			2012
Derivatives in Cash Flow Hedging Relationships
Effective portion of gain (loss) recognized in OCI on derivatives:
NYMEX/ICE natural gas contracts		$	(3,188	)	$	5,023		$	(1,855	)	$	8,020
NYMEX gasoline and heating oil contracts		147			83			203			133
Interest rate swaps		(4,549		)	—			(4,549		)	—
Total		$	(7,590	)	$	5,106		$	(6,201	)	$	8,153
Effective portion of gain (loss) reclassified from AOCI to income:
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	$	302		$	4,048		$	(1,661	)	$	10,788
	Gas Marketing Operating Expenses	(318		)	(4,445		)	(652		)	(8,369		)
Sub-total		(16		)	(397		)	(2,313		)	2,419
NYMEX gasoline and heating oil contracts	Other Gas Utility Operating Expenses	38			(11		)	85			3
Total		$	22		$	(408	)	$	(2,228	)	$	2,422
Ineffective portion of gain (loss) on derivatives recognized in income:
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	$	(87	)	$	50		$	(412	)	$	69
	Gas Marketing Operating Expenses	(44		)	(90		)	(129		)	(196		)
Sub-total		(131		)	(40		)	(541		)	(127		)
NYMEX gasoline and heating oil contracts	Other Gas Utility Operating Expenses	(31		)	28			(132		)	34
Total		$	(162	)	$	(12	)	$	(673	)	$	(93	)
Derivatives Not Designated as Hedging Instruments *
Gain (loss) recognized in income on derivatives:
Natural gas commodity contracts	Gas Marketing Operating Revenues	$	1,745		$	1,557		$	775		$	790
	Gas Marketing Operating Expenses	—			—			—			687
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	(1,679		)	1,478			(612		)	1,548
	Gas Marketing Operating Expenses	—			30			—			30
NYMEX gasoline and heating oil contracts	Other Income and (Income Deductions) - Net	13			12			46			13
Total		$	79		$	3,077		$	209		$	3,068

* 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 Gas Utility Natural and Propane Gas operating expenses when they are recovered through the PGA Clause and reflected in customer billings.

18

Fair Value of Derivative Instruments in the Consolidated Balance Sheet at March 31, 2013
	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	Accounts Receivable - Other	$	520		Accounts Receivable - Other	$	2,993
NYMEX/ICE natural gas contracts	Other Deferred Charges	5			Other Deferred Charges	—
NYMEX gasoline and heating oil contracts	Derivative Instrument Assets	312			Derivative Instrument Assets	—
Interest rate swaps	Other Current Liabilities	—			Other Current Liabilities	4,549
Sub-total		837				7,542
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Derivative Instrument Assets	10,862			Derivative Instrument Assets	339
	Accounts Receivable – Other	2			Accounts Receivable – Other	457
Natural gas commodity contracts	Derivative Instrument Assets	2,943			Derivative Instrument Assets	227
	Other Current Liabilities	62			Other Current Liabilities	787
NYMEX gasoline and heating oil contracts	Derivative Instrument Assets	10			Derivative Instrument Assets	—
Sub-total		13,879				1,810
Total derivatives		$	14,716			$	9,352
Fair Value of Derivative Instruments in the Consolidated Balance Sheet at September 30, 2012
	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	Accounts Receivable - Other	$	405		Accounts Receivable - Other	$	3,413
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	334			Accounts Receivable - Other	—
Sub-total		739				3,413
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Accounts Receivable - Other	8,000			Accounts Receivable - Other	10,731
Natural gas commodity contracts	Derivative Instrument Assets	3,150			Derivative Instrument Assets	295
	Other Current Liabilities	4			Other Current Liabilities	137
	Other Deferred Charges	19			Other Deferred Charges	—
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	10			Accounts Receivable - Other	—
Sub-total		11,183				11,163
Total derivatives		$	11,922			$	14,576

19

Fair Value of Derivative Instruments in the Consolidated Balance Sheet at March 31, 2012
	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	$	3,545		Derivative Instrument Assets	$	3,242
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	72			Accounts Receivable - Other	—
Sub-total		3,617				3,242
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Accounts Receivable - Other	709			Accounts Receivable - Other	36,437
	Derivative Instrument Assets	2,238			Derivative Instrument Assets	474
Natural gas commodity contracts	Derivative Instrument Assets	4,176			Derivative Instrument Assets	490
	Other Deferred Charges	217			Other Deferred Charges	—
	Other Current Liabilities	48			Other Current Liabilities	721
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	9			Accounts Receivable - Other	—
Sub-total		7,397				38,122
Total derivatives		$	11,014			$	41,364

* 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:

(Thousands)	Mar. 31, 2013			Sept. 30, 2012			Mar. 31, 2012
Fair value of asset derivatives presented above	$	14,716		$	11,922		$	11,014
Fair value of cash margin receivables offset with derivatives	2,928			5,478			35,648
Netting of assets and liabilities with the same counterparty	(11,618		)	(14,526		)	(41,148		)
Total	$	6,026		$	2,874		$	5,514
Derivative Instrument Assets, per Consolidated Balance Sheets:
Derivative instrument assets	$	6,021		$	2,855		$	5,297
Other deferred charges	5			19			217
Total	$	6,026		$	2,874		$	5,514
Fair value of liability derivatives presented above	$	9,352		$	14,576		$	41,364
Fair value of cash margin payables offset with derivatives	7,540			83			457
Netting of assets and liabilities with the same counterparty	(11,618		)	(14,526		)	(41,148		)
Derivative instrument liabilities, per Consolidated Balance Sheets*	$	5,274		$	133		$	673

*    Included in the Other line of the Current Liabilities section

Additionally, at March 31, 2013, September 30, 2012, and March 31, 2012, the Company had $1.3 million, $10.0 million, and $8.2 million, respectively, in cash margin receivables not offset with derivatives, that are presented in Accounts Receivable - Other.

20

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 $21.9 million at March 31, 2013. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $19.5 million Accounts receivable attributable to utility companies and their marketing affiliates comprised $13.7 million of total accounts receivable at March 31, 2013, while net receivable amounts from these customers, reflecting netting arrangements, were $11.6 million. LER also has concentrations of credit risk with certain individually significant counterparties. At March 31, 2013, the amounts included in accounts receivable from LER’s five largest counterparties (in terms of net accounts receivable exposure), were $23.9 million. 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 $22.4 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 March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013		2012
Interest income	$	257		$	316		$	663	$	664
Net investment (loss) gain	1,174			1,164			1,104		2,194
Other income	9			11			77		11
Other income deductions	(100		)	(110		)	580		451
Other Income and (Income Deductions) – Net	$	1,340		$	1,381		$	2,424	$	3,320

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10.        INFORMATION BY OPERATING SEGMENT

All of Laclede Group’s subsidiaries are wholly owned. In the first quarter of fiscal year 2013, the Company retitled its segment names. The Gas Utility segment, previously titled Regulated Gas Distribution, 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 Gas Marketing segment, previously titled Non-Regulated Gas Marketing, 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 became operational in January 2012 and utilizes natural gas storage contracts for providing natural gas sales. 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, among other activities, real estate development, the compression of natural gas, and financial investments in other enterprises. These operations are conducted through seven subsidiaries. Other also includes Laclede Gas’ non-regulated business activities, which are comprised of its propane storage and related services. Accounting policies are described in Note 1. Intersegment transactions include sales of natural gas from Laclede Gas to LER, propane storage services provided by Laclede Gas to Laclede Pipeline Company, sales of natural gas from LER to Laclede Gas, and propane transportation services provided by Laclede Pipeline Company to Laclede Gas.

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 also excludes the after-tax impact of costs related to unique acquisition, divestiture, and restructuring activities.

			Gas						Unallocated and
(Thousands)	Gas Utility		Marketing			Other			Eliminations			Consolidated
Three Months Ended
March 31, 2013
Revenues from external customers	$	354,097	$	41,255		$	2,261		$	—		$	397,613
Intersegment revenues	9,814		(2,332		)	319			(7,801		)	—
Total Operating Revenues	363,911		38,923			2,580			(7,801		)	397,613
Net Economic Earnings (Losses)	30,197		2,368			(51		)	—			32,514
Total assets	1,821,372		202,012			126,668			(140,954		)	2,009,098
Six Months Ended
March 31, 2013
Revenues from external customers	$	604,208	$	96,504		$	3,904		$	—		$	704,616
Intersegment revenues	10,494		4,574			578			(15,646		)	—
Total Operating Revenues	614,702		101,078			4,482			(15,646		)	704,616
Net Economic Earnings (Losses)	55,538		5,649			(440		)	—			60,747
Total assets	1,821,372		202,012			126,668			(140,954		)	2,009,098
Three Months Ended
March 31, 2012
Revenues from external customers	$	298,623	$	66,045		$	381		$	—		$	365,049
Intersegment revenues	—		1,927			259			(9,060		)	(6,874		)
Total Operating Revenues	298,623		67,972			640			(9,060		)	358,175
Net Economic Earnings	25,772		2,545			110			—			28,427
Total assets	1,680,948		177,129			151,646			(251,592		)	1,758,131
Six Months Ended
March 31, 2012
Revenues from external customers	$	549,522	$	218,022		$	1,544		$	—		$	769,088
Intersegment revenues	3		8,538			519			(9,060		)	—
Total Operating Revenues	549,525		226,560			2,063			(9,060		)	769,088
Net Economic Earnings	46,851		5,984			485			—			53,320
Total assets	1,680,948		177,129			151,646			(251,592		)	1,758,131

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Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income
	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2013			2012			2013			2012
Total Net Economic Earnings above	$	32,514		$	28,427		$	60,747		$	53,320
Add: Unrealized (loss) gain on energy-related derivative
contracts, net of tax	(587		)	1,963			(1,026		)	2,244
Add:  Lower of cost or market inventory
adjustments, net of tax	—			(562		)	—			(562		)
Add:  Realized (loss) gain on economic hedges prior to sale of
the physical commodity, net of tax	(9		)	(144		)	22			(144		)
Add:  Acquisition, divestiture, and restructuring activities,
net of tax	(1,676		)	—			(3,933		)	—
Net Income	$	30,242		$	29,684		$	55,810		$	54,858

11.        COMMITMENTS AND CONTINGENCIES

Commitments

Laclede Gas and LER have entered into various contracts, expiring on dates through fiscal year 2018, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at March 31, 2013 are estimated at approximately $410 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 customer relationship and work management, financial, and supply chain software applications to enhance its technology, customer service, and business processes. At March 31, 2013, the Company was contractually committed to costs of approximately $1.5 million related to this project, with additional expenditures to be incurred throughout the project’s life.

Refer to Note 12, Acquisition Agreements, for information about Laclede Group's commitments associated with the pending acquisitions of substantially all of the assets and liabilities of Missouri Gas Energy (MGE) and New England Gas Company (NEG) and the subsequent agreement with Algonquin Power & Utilities Corp. (APUC) that will allow an APUC subsidiary to acquire the Company's rights to purchase the assets of NEG.

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.

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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 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 in conjunction with other potentially responsible parties that are willing to contribute to such efforts in a meaningful and equitable fashion. Further correspondence from the Missouri Attorney General dated April 12, 2012, and November 28, 2012, encouraged Laclede Gas and other present and former owners of the site to move forward with further site investigation for possible remediation via enrollment in the Missouri Department of Natural Resources Brownfields/Voluntary Cleanup Program (BVCP) in lieu of being subjected to enforcement action by the United States Environmental Protection Agency, Region VII. Accordingly, Laclede Gas and the other former and current owners of the site each have entered into, or are in the process of entering into, Provisional Cost Sharing and Environmental Response Agreements enabling Laclede Gas to enroll the property in the BVCP and to fund and conduct additional investigation of the property. Laclede Gas enrolled the site in the BVCP as of April 1, 2013.

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 associated 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.

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The MoPSC Staff previously proposed disallowances related to Laclede Gas' recovery of its purchased gas costs totaling $6.0 million pertaining to Laclede Gas' purchase of gas from a marketing affiliate, LER, applicable to fiscal years 2005 through 2007. The MoPSC Staff also proposed a number of non-monetary recommendations, based on its review of gas costs for fiscal years 2008 through 2011. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments. Management, after discussion with counsel, continues to believe the final outcome of these matters will not have a material effect on the Company's financial position, results of operations, or cash flows. Laclede Gas is currently in discussions with the MoPSC Staff and other parties to resolve these matters.

In connection with its review of these affiliate transactions, Laclede Gas objected, on the grounds of relevance, to MoSPC data requests seeking to obtain from LER certain of LER's proprietary documents unrelated to Laclede Gas' purchases from LER. 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 stating the Staff failed to adhere to 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. These Orders were later reversed by the Cole County Circuit Court, but ultimately upheld by the Western District Court of Appeals. On March 19, 2013, the Missouri Supreme Court declined Laclede Gas' request to review the opinion of the Western District Court of Appeals relating to the information-related requirements of the 2001 Order. As a result, additional LER documentation may need to be shared with the MoPSC staff. In addition, certain related complaints filed by the MoPSC Staff on October 6, 2010 and a counterclaim by Laclede Gas against Staff are still pending before the Commission. Management, after discussion with counsel, continues to believe the final outcome of these matters will not have a material effect on the Company's financial position, results of operations, or cash flows. Laclede Gas is currently in discussions with the MoPSC Staff and other parties to resolve these matters.

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, or cash flows 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. On January 31, 2013, the bankruptcy trustee received approval from the court to make certain additional distributions to customers. As a result of this action, Laclede Gas and LER received partial cash distributions totaling $0.7 million and $0.1 million, respectively, in April 2013. As of April 29, 2013, Laclede Gas and LER had $0.9 million and $0.2 million, respectively, on deposit with MF Global that remain unavailable pending final resolution by the bankruptcy trustee. Regarding the funds that remain outstanding after this partial distribution, management is currently unable to predict when, or to what extent, these funds will be returned. Management does not believe that the Company's exposure is material.

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.

12.    ACQUISITION AGREEMENTS

On December 14, 2012, Laclede Group entered into purchase and sale agreements, subject to customary closing adjustments, to acquire for $1.035 billion (collectively, the Transaction) from Southern Union Company (SUG), an affiliate of Energy Transfer Equity, L.P. and Energy Transfer Partners, L.P., substantially all of the assets and liabilities of SUG's MGE and NEG divisions (collectively, the Utilities). The Utilities are engaged in the distribution of natural gas on a regulated basis in western Missouri and in southeastern Massachusetts.

The Transaction is targeted to close before the end of fiscal year 2013, subject to customary closing conditions, including regulatory approvals from the MoPSC and the Massachusetts Department of Public Utilities. On January 22, 2013, the Federal Trade Commission notified the Company of the early termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended. No shareholder approval is required to complete the Transaction, and each of the entities has received all necessary approvals from their boards of directors.

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The purchase and sale agreements contain certain termination rights for both the Company and SUG, including, among others, the right to terminate if the Transaction is not completed by October 14, 2013 (subject to up to four 30-day extensions under certain circumstances related to obtaining required regulatory approvals). In the event that SUG terminates the MGE acquisition agreement as a result of the failure of Laclede Group to obtain financing, the Company may be required to pay SUG a "reverse break up" fee of $73.1 million, which amount will operate as liquidated damages and a cap on such liability for such breach.

Laclede Group's agreement to acquire MGE for $975 million, via the newly formed wholly owned subsidiary Plaza Missouri Acquisition, Inc., was assigned by Laclede Group to Laclede Gas on January 11, 2013. Subsequently, on January 14, 2013, the Company filed an application with the MoPSC for approval to acquire the assets of MGE from SUG, and the Company continues to work with the MoPSC staff to respond to their requests for additional information supporting the Company's pending application.

Similarly, the agreement to acquire NEG for $60 million, including approximately $19.5 million of assumed NEG debt, is contracted through a second newly formed wholly owned subsidiary of Laclede Group, Plaza Massachusetts Acquisition, Inc. (Plaza Massachusetts). On February 11, 2013, the Company announced that it entered into an agreement with Algonquin Power & Utilities Corp. (APUC) that will allow an APUC subsidiary, through its acquisition of the stock of Plaza Massachusetts, to acquire the rights to purchase the assets of NEG, subject to certain approvals and conditions. Under the terms of this agreement, the Company will receive $11 million from APUC at closing. Further, APUC has deposited $3.0 million in an escrow account that will be paid to SUG at closing. The sale of NEG to APUC is subject to approval from the Massachusetts Department of Public Utilities (MDPU), and a filing that was made by the Company and SUG with the MDPU on January 24, 2013, for approval of the acquisition of NEG, was amended on February 19, 2013 to include APUC. On March 15, 2013, the MDPU issued a procedural schedule setting the case for hearing during the last week in June 2013. Laclede Group remains obligated to acquire NEG in the event that APUC is not able to satisfy all conditions for closing on or before October 14, 2013, although the Company believes this scenario would be unlikely. The Company's agreement with APUC is not anticipated to impact the MGE transaction.

The Transaction is supported by existing company cash and Laclede Group's fully committed $1.020 billion bridge facility with Wells Fargo Bank, National Association. That bridge facility was syndicated to a group of nine financial institutions in January 2013. The Company anticipates permanent financing to be a combination of long-term debt and equity.

The Company continues to incur costs associated with the evaluation, approval and financing of the Transaction. During the three and six months ended March 31, 2013, Laclede Group recorded $1.7 million and $3.9 million, respectively, net of tax, of third-party expenses associated with the Transaction.

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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 current 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, expiration of existing supply and transportation arrangements that are not replaced with contracts with similar terms and pricing, 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.

In addition, actual results may differ materially from those contemplated in any forward-looking statement due to the timing and likelihood of the closing of i) the purchase of substantially all of the assets and liabilities of Missouri Gas Energy (MGE) from Southern Union Company (SUG), ii) the Company's agreement with Algonquin Power & Utilities Corp. (APUC) to allow an APUC subsidiary to acquire the Company's rights to purchase the assets of New England Gas Company (NEG), and iii) the other factors discussed in "Risks Related To The Company's Acquisition Agreements With Southern Union Company And Algonquin Power & Utilities Corp." under Part II. Item 1A on page 45 of this Report. Refer to Acquisition Agreements on page 28 for additional information.

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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.

ACQUISITION AGREEMENTS

In December 2012, Laclede Group, through two newly formed wholly owned subsidiaries, Plaza Missouri Acquisition , Inc. and Plaza Massachusetts Acquisition, Inc., entered into definitive purchase and sale agreements with SUG to acquire substantially all of the assets of MGE and NEG. On February 11, 2013, the Company announced that it entered into an agreement with APUC that will allow an APUC subsidiary to acquire the Company's rights to purchase the assets of NEG, subject to certain approvals and conditions. The Company's agreement with APUC is not expected to impact the MGE transaction. These transactions are targeted to be completed before the end of fiscal year 2013. The strategic rationale for Laclede Group is described below:

• With a larger market capitalization and enterprise value, the Company expects to have improved trading liquidity and better access to the capital markets. It plans to be able to support growth initiatives in new markets with new customers.

• Laclede Group will serve Missouri's two largest metropolitan areas in a state where it already has a working relationship with regulators.

• The acquisition of MGE is expected to be neutral to Laclede Group's earnings per share in the first full year following closing and accretive thereafter. The acquisition of MGE is expected to be immediately accretive to cash flow.

Completion of the pending transactions, including the agreement with APUC relative to NEG, is subject to customary closing conditions, including regulatory approvals from the Missouri Public Service Commission (MoPSC or Commission) and the Massachusetts Department of Public Utilities. No shareholder approval is required to complete the transaction, and each of the entities has received all necessary approvals from their boards of directors. On January 22, 2013, the Federal Trade Commission notified the Company of the early termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended.

The purchase and sale agreements contain certain termination rights for both Laclede Group and SUG, and further provide for the payment of fees and expenses upon termination under specified circumstances. For additional information relating to the pending acquisitions, see Note 12, Acquisition Agreements, of the Notes of the Consolidated Financial Statements. Also refer to the Company's form 8-K filed on December 17, 2012. Subsequently, on January 11, 2013, the Company entered into an agreement to assign the MGE agreement to Laclede Group's Utility subsidiary, Laclede Gas, as described more fully in the Company's Form 8-K filed on January 14, 2013.

RESULTS OF OPERATIONS

Overview

Laclede Group’s earnings are primarily derived from its Gas Utility segment, which reflects the regulated activities of its largest subsidiary, Laclede Gas, Missouri’s largest natural gas distribution company. Laclede Gas is regulated by the MoPSC 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.

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Laclede Energy Resources, Inc. (LER), which includes its wholly owned subsidiary LER Storage Services, Inc. (LSS), is engaged in the marketing of natural gas and related activities on a non-regulated basis and is reported in the Gas Marketing segment. 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. LSS has contracted storage capacity for 1 Bcf of natural gas through January 2014. 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 mid-2013.

Other subsidiaries provide less than 10% of consolidated revenues.

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:

Gas Utility 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.

Gas Marketing Segment:

• the risks of competition;

• 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,

• 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 rate of 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.

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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, park and loan 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 and volatility risks associated with providing such services to its customers through the use of a variety of risk management activities, including 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 impacts of new pipeline infrastructure and surplus natural gas supplies on natural gas commodity prices. Further, LER's profitability will likely be impacted by the effects of the expiration of certain of its natural gas supply and transportation agreements if those contracts cannot be replaced and/or renewed with arrangements with similar terms and pricing.

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.

In response to new pipeline infrastructure and more abundant natural gas supplies, LER may have the opportunity to enter into subsequent offsetting purchase or sale transactions at the same location in order to satisfy its commitments without incurring fuel cost to transport natural gas to a different location. Thus, LER cannot be certain that all of its wholesale purchase and sale transactions will settle physically. As such, certain transactions entered into on or after January 1, 2012 are designated as trading activities for financial reporting purposes, due to their settlement characteristics, rather than elected for normal purchases or normal sales designations under generally accepted accounting principles (GAAP). Results of operations from trading activities are reported on a net basis (instead of a gross basis) in Gas Marketing Operating Revenues, which may cause reductions in and/or volatility in the Company’s operating revenues, but has no effect on operating income or net income.

In the course of its business, LER enters into commitments associated with the purchase or sale of natural gas. In accordance with GAAP, some of LER’s purchase and sale transactions are not recognized in earnings until the natural gas is physically delivered, while other energy-related transactions, including those designated as trading activities, are required to be accounted for as derivatives, with the changes in their fair value (representing unrealized gains or losses) recorded in earnings in periods prior to settlement. 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 (non-GAAP), as discussed below.

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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 and 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 and 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 excludes the effect of costs related to unique acquisition, divestiture, and restructuring activities, when evaluating on-going performance, and therefore excludes 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.

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Quarter Ended March 31, 2013

Reconciliation of Consolidated Net Economic Earnings (Non-GAAP) to Consolidated Net Income (GAAP)
(Millions, except per share amounts)		Gas Utility		Gas Marketing			Unallocated & Other			Total			Per Share Amounts**
Quarter Ended March 31, 2013
	Net Economic Earnings (Losses) (Non-GAAP)	$	30.2	$	2.4		$	(0.1	)	$	32.5		$	1.44
	Add:  Unrealized gain (loss) on energy-related      derivatives*	—		(0.6		)	—			(0.6		)	(0.03		)
	Add: Acquisition, divestiture and restructuring activities*	—		—			(1.7		)	(1.7		)	(0.07		)
	Net Income (Loss) (GAAP)	$	30.2	$	1.8		$	(1.8	)	$	30.2		$	1.34
Quarter Ended March 31, 2012
	Net Economic Earnings (Losses) (Non-GAAP)	$	25.8	$	2.5		$	0.1		$	28.4		$	1.27
	Add:  Unrealized gain (loss) on energy-related      derivatives*	—		2.0			—			2.0			0.09
	Add:  Lower of cost or market inventory adjustments*	—		(0.6		)	—			(0.6		)	(0.03		)
	Add:  Realized gain (loss) on economic hedges prior      to the sale of the physical commodity*	—		(0.1		)	—			(0.1		)	(0.01		)
	Add: Acquisition, divestiture and restructuring activities*	—		—			—			—			—
	Net Income (Loss) (GAAP)	$	25.8	$	3.8		$	0.1		$	29.7		$	1.32

* 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 the pre-tax reconciling items. For the quarters ended March 31, 2013 and 2012, the total net amount of income tax (benefit) expense included in the reconciling items above is ($1.4) million and $0.8 million, respectively.

** 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 $30.2 million for the quarter ended March 31, 2013, compared with $29.7 million for the quarter ended March 31, 2012. Basic and diluted earnings per share for the quarter ended March 31, 2013 were $1.34, compared with basic and diluted earnings per share of $1.33 and $1.32, respectively, for the quarter ended March 31, 2012. Earnings increased compared to last year primarily due to improved results reported by Laclede Group's Gas Utility Segment. These factors were partially offset by lower net income reported by the Gas Marketing Segment and acquisition costs incurred this quarter totaling $1.7 million, net of tax, or $0.07 per share, associated with agreements to acquire certain assets and liabilities from SUG, as described previously. Acquisition-related costs, among other items, are excluded from net economic earnings, which were $32.5 million for the quarter ended March 31, 2013, compared with $28.4 million for the same quarter last year. Net economic earnings per share were $1.44 for the quarter ended March 31, 2013, compared with $1.27 for the quarter ended March 31, 2012.

Gas Utility net income and net economic earnings both increased by $4.4 million for the quarter ended March 31, 2013, compared with the quarter ended March 31, 2012. The increase was primarily due to the following factors, quantified on a pre-tax basis:

• increased sales margins reflecting colder weather this year totaling $4.4 million;

• decreases in employee benefit expenses of $2.8 million; and

• higher Infrastructure System Replacement Surcharge (ISRS) revenues totaling $1.1 million.

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These benefits were partially offset by higher depreciation and amortization expenses totaling $1.1 million.

The Gas Marketing segment reported GAAP earnings totaling $1.8 million, a decrease of $2.0 million compared with the same quarter last year. Net economic earnings for the quarter ended March 31, 2013 decreased $0.1 million from the quarter ended March 31, 2012. The decrease in net economic earnings was primarily attributable to reduced sales margins, reflecting low price volatility and basis differentials in the current natural gas market and the expiration of a favorable supply contract, largely offset by higher transaction volumes and the realization of seasonal storage spreads. On a GAAP basis, LER's results were further impacted by the effect of higher net unrealized losses from certain of LER's energy-related derivative contracts.

Other net income and net economic earnings decreased $1.9 million and $0.2 million, respectively, compared with the same period last year. The decrease in net income is primarily due to unallocated expenses during the quarter ended March 31, 2013, attributable to the pending acquisition of MGE and NEG from SUG totaling $1.7 million, net of tax.

Gas Utility 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.

Gas Utility Operating Revenues for the quarter ended March 31, 2013 were $354.1 million, or $55.5 million more than the same period last year. Temperatures experienced in the Utility’s service area during the quarter ended March 31, 2013 were 45.7% colder than the same quarter last year and 3.5% colder than normal. Last year's temperatures were the warmest on record. Total system therms sold and transported were 413.0 million for the quarter ended March 31, 2013, compared with 305.2 million for the same period last year. Total off-system therms sold and transported were 102.0 million for the quarter ended March 31, 2013, compared with 130.0 million for the same period last year. The increase in Gas Utility Operating Revenues was primarily attributable to the following factors:

(Millions)
Higher system sales volumes and other variations	$	60.2
Higher prices charged for off-system sales	10.9
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)	(9.4		)
Lower off-system sales volumes (reflecting less favorable market conditions as described in greater      detail in the Results of Operations - Overview)	(7.3		)
Higher ISRS revenues	1.1
Total Variation	$	55.5

Gas Utility Operating Expenses

Gas Utility Operating Expenses for the quarter ended March 31, 2013 increased $59.4 million from the same quarter last year. Natural and propane gas expense increased $59.3 million, or 34.6%, from last year’s level, primarily attributable to increased system volumes purchased for sendout and higher off-system gas expense, partially offset by lower rates charged by our suppliers. Other operation and maintenance expense decreased $2.6 million, or 6.0%, primarily due to lower employee benefit expenses, a lower provision for uncollectible accounts, a higher rate of overheads capitalized, and reduced customer accounts expenses, partially offset by increased charges for outside services. Depreciation and amortization expense increased $1.1 million primarily due to additional depreciable property. Taxes, other than income taxes, increased $1.7 million, or 8.3%, primarily due to increased gross receipts taxes (attributable to increased system sales revenues).

Gas Marketing Operating Revenues and Operating Expenses

Gas Marketing Operating Revenues and Operating Expenses decreased $18.2 million and $25.8 million, respectively, primarily due to the effect of recording certain transactions on a net basis (instead of a gross basis) which had no effect on earnings, as described in greater detail in Results of Operations – Overview. The decreases were partially offset by higher volumes purchased and sold as well as higher per unit gas prices.

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Other Operating Revenues and Operating Expenses

Other Operating Revenues increased by $2.1 million, primarily due to a sale of propane inventory by Laclede Pipeline Company during the quarter ended March 31, 2013. The increase in Other Operating Expenses, totaling $4.6 million, was primarily due to the acquisition expenses discussed above and expenses associated with the aforementioned propane sale. Additional acquisition expenses are expected to be incurred prior to the closing of the Transaction.

Interest Charges

Interest charges during the quarter ended March 31, 2013 increased $0.4 million from the same period last year primarily due to expenses associated with the Company's bridge loan facility, partially offset by lower interest on long-term debt. The slightly lower interest on long-term debt reflects the net effect of the October 2012 maturity of $25 million of 6 1/2% first mortgage bonds and the December 2012 and March 2013 issuances of additional long-term debt of $25 million and $100 million, respectively. Average short-term interest rates were 0.3% for both the quarters ended March 31, 2013 and 2012. Average short-term borrowings were $46.7 million for the quarter ended March 31, 2013, compared with $68.7 million for the quarter ended March 31, 2012.

Six Months Ended March 31, 2013

Reconciliation of Consolidated Net Economic Earnings (Non-GAAP) to Consolidated Net Income (GAAP)
(Millions, except per share amounts)		Gas Utility			Gas Marketing			Unallocated & Other			Total			Per Share Amounts**
Six Months Ended March 31, 2013
	Net Economic Earnings (Losses) (Non-GAAP)	$	55.5		$	5.6		$	(0.4	)	$	60.7		$	2.69
	Add:  Unrealized gain (loss) on energy-related      derivatives*	(0.1		)	(0.9		)	—			(1.0		)	(0.05		)
	Add: Acquisition, divestiture and restructuring activities*	—			—			(3.9		)	(3.9		)	(0.17		)
	Net Income (Loss) (GAAP)	$	55.4		$	4.7		$	(4.3	)	$	55.8		$	2.47
Six Months Ended March 31, 2012
	Net Economic Earnings (Losses) (Non-GAAP)	$	46.8		$	6.0		$	0.5		$	53.3		$	2.38
	Add:  Unrealized gain (loss) on energy-related      derivatives*	0.1			2.2			—			2.3			0.11
	Add:  Lower of cost or market inventory adjustments*	—			(0.6		)	—			(0.6		)	(0.03		)
	Add:  Realized gain (loss) on economic hedges prior      to the sale of the physical commodity*	—			(0.1		)	—			(0.1		)	(0.01		)
	Net Income (Loss) (GAAP)	$	46.9		$	7.5		$	0.5		$	54.9		$	2.45

* 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 the pre-tax reconciling items. For the six months ended March 31, 2013 and 2012, the total net amount of income tax (benefit) expense included in the reconciling items above is ($3.0) million and $1.0 million, respectively.

** 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 $55.8 million for the six months ended March 31, 2013, compared with $54.9 million for the six months ended March 31, 2012. Basic and diluted earnings per share for the six months March 31, 2013 were $2.48 and $2.47, respectively, compared with basic and diluted earnings per share of $2.45 for the six months ended March 31, 2012. Earnings increased compared to last year primarily due to improved results reported by Laclede Group's Gas Utility Segment, partially offset by acquisition costs incurred during the period totaling $3.9 million, net of tax, or $0.17 per share, associated with agreements to acquire certain assets and liabilities from SUG, as described previously. Additionally, earnings were impacted by decreased income from the Gas Marketing Segment. Acquisition-related costs, among other items, are excluded from net economic earnings, which were $60.7 million for the six months ended March 31, 2013, compared with $53.3 million for the same period last year. Net economic earnings per share were $2.69 for the six months ended March 31, 2013, compared with $2.38 for the six months ended March 31, 2012.

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Gas Utility net income and net economic earnings increased by $8.5 million and $8.7 million, respectively for the six months ended March 31, 2013, compared with the six months ended March 31, 2012. The increase was primarily due to the following factors, quantified on a pre-tax basis:

• increased sales margins reflecting colder weather this year totaling $5.4 million;

• decreases in employee benefit expenses totaling $3.0 million;

• a lower provision for uncollectible accounts totaling $2.9 million; and

• higher ISRS revenues totaling $2.4 million.

These benefits were partially offset by higher depreciation and amortization expenses totaling $2.0 million.

The Gas Marketing segment reported GAAP earnings totaling $4.7 million, a decrease of $2.8 million compared with the same period last year. Net economic earnings for the six months ended March 31, 2013 decreased $0.4 million from the six months ended March 31, 2012. The decrease in net economic earnings was primarily attributable to reduced sales margins, reflecting current market conditions and the expiration of a favorable supply contract, largely offset by higher transaction volumes. On a GAAP basis, LER's results were further impacted by the effect of higher net unrealized losses from certain of LER's energy-related derivative contracts.

Other net income and net economic earnings decreased $4.8 million and $0.9 million, respectively, compared with the same period last year. The decrease in net income is primarily due to unallocated expenses during the six months ended March 31, 2013, attributable to the pending acquisition of MGE and NEG from SUG totaling $3.9 million, net of tax.

Gas Utility 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.

Gas Utility Operating Revenues for the six months ended March 31, 2013 were $604.2 million, or $54.7 million more than the same period last year. Temperatures experienced in the Utility’s service area during the six months ended March 31, 2013 were 32.6% colder than the same period last year, but 1.6% warmer than normal. Last year's temperatures were the warmest on record. Total system therms sold and transported were 674.1 million for the six months ended March 31, 2013, compared with 543.7 million for the same period last year. Total off-system therms sold and transported were 182.4 million for the six months ended March 31, 2013, compared with 228.2 million for the same period last year. The increase in Gas Utility Operating Revenues was primarily attributable to the following factors:

(Millions)
Higher system sales volumes and other variations	$	74.2
Lower wholesale gas costs passed on to Utility customers (subject to prudence review by the MoPSC)	(21.0		)
Lower off-system sales volumes (reflecting less favorable market conditions as described in greater      detail in the Results of Operations - Overview)	(13.5		)
Higher prices charged for off-system sales	12.6
Higher ISRS revenues	2.4
Total Variation	$	54.7

Gas Utility Operating Expenses

Gas Utility Operating Expenses for the six months ended March 31, 2013 increased $47.0 million from the same period last year. Natural and propane gas expense increased $49.0 million, or 15.4%, from last year’s level, primarily attributable to increased system volumes purchased for sendout and higher off-system gas expense, partially offset by lower rates charged by our suppliers. Other operation and maintenance expenses decreased $5.8 million, or 6.7%, primarily due to lower employee benefit expenses, a lower provision for uncollectible accounts, a higher rate of overheads capitalized, and reduced customer accounts expenses, partially offset by increased charges for outside services. Depreciation and amortization expense increased $2.0 million primarily due to additional depreciable property. Taxes, other than income taxes, increased $1.8 million, or 5.2%, primarily due to increased gross receipts taxes (attributable to increased system sales revenues).

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Gas Marketing Operating Revenues and Operating Expenses

Gas Marketing Operating Revenues and Operating Expenses decreased $121.5 million and $121.0 million, respectively, primarily due to the effect of recording certain transactions on a net basis (instead of a gross basis) which had no effect on earnings, as described in greater detail in Results of Operations – Overview. The decreases were partially offset by higher volumes purchased and sold and, to a lesser extent, higher per unit gas prices.

Other Operating Revenues and Operating Expenses

Other Operating Revenues increased by $2.4 million, primarily due to a sale of propane inventory by Laclede Pipeline Company during the six months ended March 31, 2013. The increase in Other Operating Expenses, totaling $9.3 million, was primarily due to the acquisition-related expenses discussed above and expenses associated with the aforementioned propane sale. Additional acquisition expenses are expected to be incurred prior to the closing of the Transaction.

Other Income and (Income Deductions) - Net

Other Income and (Income Deductions) - Net decreased $0.9 million primarily due to lower net investment gains.

Interest Charges

Interest charges during the six months ended March 31, 2013 increased $0.1 million from the same period last year primarily due expenses associated with the Company's bridge loan facility, partially offset by lower interest on long-term debt. The lower interest on long-term debt reflects the net effect of the October 2012 maturity of $25 million of 6 1/2% first mortgage bonds and the December 2012 and March 2013 issuances of additional long-term debt of $25 million and $100 million, respectively. Average short-term interest rates were 0.3% for both the six months ended March 31, 2013 and 2012. Average short-term borrowings were $61.0 million for the six months ended March 31, 2013, compared with $75.0 million for the six months ended March 31, 2012.

Income Taxes

The $1.7 million decrease in income taxes was primarily due to lower pre-tax income and various property-related deductions.

REGULATORY AND OTHER MATTERS

The MoPSC Staff previously proposed disallowances related to Laclede Gas' recovery of its purchased gas costs totaling $6.0 million pertaining to Laclede Gas' purchase of gas from a marketing affiliate, LER, applicable to fiscal years 2005 through 2007. The MoPSC Staff also proposed a number of non-monetary recommendations, based on its review of gas costs for fiscal years 2008 through 2011. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments. Management, after discussion with counsel, continues to believe the final outcome of these matters will not have a material effect on the Company's financial position, results of operations, or cash flows. Laclede Gas is currently in discussions with the MoPSC Staff and other parties to resolve these matters.

In connection with its review of these affiliate transactions, Laclede Gas objected, on the grounds of relevance, to MoSPC data requests seeking to obtain from LER certain of LER's proprietary documents unrelated to Laclede Gas' purchases from LER. 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 stating the Staff failed to adhere to 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. These Orders were later reversed by the Cole County Circuit Court, but ultimately upheld by the Western District Court of Appeals. On March 19, 2013, the Missouri Supreme Court declined Laclede Gas' request to review the opinion of the Western District Court of Appeals relating to the information-related requirements of the 2001 Order. As a result, additional LER documentation may need to be shared with the MoPSC staff. In addition, certain related complaints filed by the MoPSC Staff on October 6, 2010 and a counterclaim by Laclede Gas against Staff are still pending before the Commission. Management, after discussion with counsel, continues to believe the final outcome of these matters will not have a material effect on the Company's financial position, results of operations, or cash flows. Laclede Gas is currently in discussions with the MoPSC Staff and other parties to resolve these above matters.

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On December 21, 2012, Laclede Gas filed tariff sheets in a new general rate case proceeding that are designed to increase the Utility's total revenues by $43.6 million, net of current annualized ISRS revenues. On December 27, 2012, the MoPSC suspended implementation of the Utility's proposed rates and set the case for hearing in August 2013.

On January 14, 2013, the Company filed an application with the MoPSC for approval to acquire the assets of MGE from SUG as reported in the Acquisition Agreements section on page 28. A similar filing was made with the Massachusetts Department of Public Utilities (MDPU) on January 24, 2013 for approval of the acquisition of NEG. On March 15, 2013, the MDPU issued a procedural schedule setting the case for hearing during the last week in June 2013.

Also on January 14, 2013, the Utility made an ISRS filing with the Commission and an increase of $4.8 million was approved by the MoPSC effective March 15, 2013.

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, or cash flows of the Company.

CRITICAL ACCOUNTING POLICIES

Our discussion and analysis of our financial condition, results of operations, liquidity, and capital resources is based upon our consolidated financial statements, which have been prepared in accordance with 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, 2012 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 six months ended March 31, 2013.

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, 2012.

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.

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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, the seasonality of accounts receivable balances, 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 provided by operating activities was $142.4 million for the six months ended March 31, 2013, compared with $71.5 million for the same period last year. The variation is primarily associated with the timing of collections of gas cost under the Utility’s PGA Clause, primarily due to reduced cash payments for margin deposits associated with the Utility's use of natural gas derivative instruments. The variation also reflects decreased cash payments for the funding of pension plans. These benefits were partially offset by changes in delayed and advance customer billings

Net cash used in investing activities for the six months ended March 31, 2013 was $64.8 million, compared with $42.1 million for the six months ended March 31, 2012. The variation primarily reflects additional capital expenditures this year for distribution plant and information technology investments.

Net cash provided by financing activities was $41.9 million for the six months ended March 31, 2013, compared with net cash used in financing activities of $63.3 million for the six months ended March 31, 2012. The variation primarily reflects the issuance of additional long-term debt this year, partially offset by the maturity of long-term debt.

LIQUIDITY AND CAPITAL RESOURCES

Cash and Cash Equivalents

Laclede Group had temporary cash investments totaling $131.3 million at March 31, 2013, earning an average interest rate of 0.1%. This includes $35.5 million held by Laclede Gas, also at an average interest rate of 0.1%. 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 ranged between $10.4 million and $131.3 million during the six months ended March 31, 2013. 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 six months ended March 31, 2013, but there were no such borrowings at March 31, 2013.

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 March 31, 2013, Laclede Gas had a syndicated line of credit in place of $300 million from seven banks, $257.1 million of which is scheduled to expire in July 2017 and $42.9 million of which is scheduled to expire in July 2016. The largest portion provided by a single bank is 17.9%. Laclede Gas’ line of credit includes a covenant limiting total debt, including short-term debt, to no more than 70% of total capitalization. As a result of certain amendments made on January 16, 2013, this maximum percentage will temporarily increase to 72.5% if the MGE acquisition is consummated. Such temporary increase would be effective from the date of consummation through September 30, 2014. As defined in the line of credit, total debt was 45% of total capitalization on March 31, 2013.

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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, $42.9 million of which expires in July 2017 and $7.1 million of which expires 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. As a result of certain amendments made on January 16, 2013, this maximum percentage will temporarily increase to 72.5% if the MGE acquisition is consummated. Such temporary increase would be effective from the date of consummation through September 30, 2014. As defined in the line of credit, this ratio stood at 42% on March 31, 2013. Occasionally, Laclede Group’s lines may be used to provide for the funding needs of various subsidiaries. There were no borrowings under Laclede Group’s lines during the six months ended March 31, 2013.

Information about Laclede Group’s consolidated short-term borrowings (excluding intercompany borrowings) during the six months ended March 31, 2013 and as of March 31, 2013, is presented below:

	Commercial Paper Borrowings
Six Months Ended March 31, 2013
Weighted average borrowings outstanding	$61.0 million
Weighted average interest rate	0.3%
Range of borrowings outstanding	$0.0 - $99.4 million
As of March 31, 2013
Borrowings outstanding at end of period	None
Weighted average interest rate	N/A

Based on average short-term borrowings for the six months ended March 31, 2013, an increase in the average interest rate of 100 basis points would decrease Laclede Group’s pre-tax earnings and cash flows by approximately $0.6 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

On March 15, 2013, Laclede Gas issued $100 million of first mortgage bonds in a private placement that had been committed to in August 2012. Of this $100 million, $55 million were issued at 3.00% for a 10-year term, maturing in March 2023, and $45 million were issued at 3.40% for a 15-year term, maturing in March 2028. Laclede Group issued $25 million of 3.31% 10-year unsecured notes in a private placement on December 14, 2012, which had also been committed to in August 2012. The proceeds were used for the repayment of short-term debt and general corporate purposes.

Laclede Gas has on file with the SEC an effective shelf registration on Form S-3 for issuance of $350 million of first mortgage bonds, unsecured debt, and preferred stock, which expires May 28, 2013. The entire amount of this shelf registration remains available to Laclede Gas at this time.

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. This authorization was originally effective through June 30, 2013. In August 2012, Laclede Gas filed a request with the MoPSC to extend this authority for an additional two years, to June 30, 2015. This extension became effective on November 23, 2012. During the six months ended March 31, 2013, pursuant to this authority, the Utility sold 43 shares of its common stock to Laclede Group for $1.7 million. As of April 26, 2013, $371.4 million remains available under this authorization. As part of its MoPSC application for approval of the acquisition of MGE, Laclede Gas requested authority to issue debt and equity securities of up to $975 million. This request is pending approval by the Commission. The amount, timing, and type of additional financing to be issued, including in connection with the MGE and NEG acquisitions as described below, will depend on cash requirements and market conditions, as well as future MoPSC authorizations.

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On October 15, 2012, Laclede Gas paid at maturity $25 million principal amount of 6 1/2% first mortgage bonds. At March 31, 2013, Laclede Gas had fixed-rate long-term debt totaling $440 million. While the remaining 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 $440 million in long-term debt, $25 million have no call option, $335 million have make-whole call options, and $80 million are callable at par on or after October 15, 2013. None of the debt has any put options.

Additionally, as of March 31, 2013, Laclede Group had fixed-rate long-term debt totaling $25 million, which is subject to changes in its fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if Laclede Group were to reacquire any of these issues in the open market prior to maturity. This debt has a make-whole call option.

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 211,127 and 203,428 shares at March 31, 2013 and April 26, 2013, 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.

In December 2012, Laclede Group announced agreements to acquire the assets of MGE and NEG for $1.015 billion, net of $19.5 million in assumed debt. Simultaneously, Laclede Group entered into a fully committed bridge facility for $1.020 billion with Wells Fargo Bank, National Association in order to fund these acquisitions. The bridge facility was syndicated by Wells Fargo Securities, LLC, to a group of nine banks, effective on January 16, 2013. The permanent financing for the acquisitions is anticipated to be a combination of long-term debt of Laclede Gas and/or Laclede Group and Laclede Group equity securities. As described in further in Acquisition Agreements, on February 11, 2013, the Company announced that it entered into an agreement with APUC that will allow an APUC subsidiary to acquire the Company's rights to purchase the assets of NEG. Laclede Group has entered into interest rate hedges for approximately 69% of the expected debt issuance to protect against the impacts of adverse movements in rates. Additional interest rate hedging may be done either by Laclede Gas or Laclede Group prior to completing the debt financing.

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 $62.6 million for the six months ended March 31, 2013, compared with $40.5 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 customer relationship and work management, financial, and supply chain software applications. Non-utility capital expenditures were $0.1 million during both the six months ended March 31, 2013 and 2012.

Consolidated capitalization at March 31, 2013 consisted of 57.9% common stock equity and 42.1% 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 the pending acquisition of MGE, 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 March 31, 2013 and at September 30, 2012, such as Accounts receivable - net, Gas stored underground, Notes payable, Accounts payable, Regulatory assets and Regulatory liabilities, and Delayed and Advance customer billings. The Consolidated Balance Sheet at March 31, 2012 is presented to facilitate comparison of these items with the corresponding interim period of the preceding fiscal year.

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CONTRACTUAL OBLIGATIONS

As of March 31, 2013, Laclede Group had contractual obligations with payments due as summarized below (in millions):

			Payments due by period
Contractual Obligations	Total		Remaining Fiscal Year 2013		Fiscal Years 2014-2015		Fiscal Years 2016-2017		Fiscal Years 2018 and thereafter
Principal Payments on Long-Term Debt	$	465.0	$	—	$	—	$	—	$	465.0
Interest Payments on Long-Term Debt	474.4		12.6		50.7		50.7		360.4
Capital Leases (a)	0.2		0.1		0.1		—		—
Operating Leases (a)	9.2		2.3		6.2		0.7		—
Purchase Obligations – Natural Gas (b)	410.1		269.6		120.4		19.3		0.8
Purchase Obligations – Other (c)	80.4		19.6		21.9		18.4		20.5
Total (d) (e)	$	1,439.3	$	304.2	$	199.3	$	89.1	$	846.7

(a) Lease obligations are primarily for office space, vehicles, and power operated equipment. Additional payments will be incurred if renewal options are exercised under the provisions of certain agreements.

(b) These purchase obligations represent the minimum payments required under existing natural gas transportation and storage contracts and natural gas supply agreements in the Gas Utility and Gas Marketing segments. These amounts reflect fixed obligations as well as obligations to purchase natural gas at future market prices, calculated using March 31, 2013 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 $7.1 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. The Company expects to make contributions to its qualified, trusteed pension plans totaling $14.5 million during the remaining six months of fiscal year 2013. Laclede Gas anticipates a $0.8 million contribution relative to its non-qualified pension plans during the remaining six months of fiscal year 2013. With regard to the postretirement benefits, the Company anticipates Laclede Gas will contribute $12.2 million to the qualified trusts and $0.4 million directly to participants from Laclede Gas’ funds during the remaining six months of fiscal year 2013. 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.

(e) The table above does not include the Company's potential payment of a "reverse break up" fee of $73.1 million that would be due in the event that SUG terminates the MGE acquisition agreement as a result of the failure of Laclede Group to obtain financing. See Note 12, Acquisition Agreements, of the Notes to Consolidated Financial Statements for further details. Also, the table does not include any anticipated additional long-term debt to finance the acquisitions.

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MARKET 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 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, options, and swap contracts traded on or cleared through the NYMEX and ICE to lock in margins. At March 31, 2013, 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, options, 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 may be designated as cash flow hedges of forecasted purchases or sales. Such accounting treatment, if elected, 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. 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 (liabilities) assets at September 30, 2012	$	(3,515	)	$	5,489		$	1,974
Changes in fair value	(3,008		)	—			(3,008		)
Settlements/purchases - net	3,599			—			3,599
Changes in cash margin	—			(1,225		)	(1,225		)
Net balance of derivative assets (liabilities) at March 31, 2013	$	(2,924	)	$	4,264		$	1,340

	At March 31, 2013
	Maturity by Fiscal Year
(Thousands)	Total			2013			2014
Fair values of exchange-traded/cleared natural gas derivatives - net	$	(2,924	)	$	(1,791	)	$	(1,133	)
MMBtu – net (short) long futures/swap/option positions	(4,690		)	(2,073		)	(2,617		)

42

Certain 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. Contracts not designated as normal purchases or normal sales, including those designated as trading activities, are accounted for as derivatives with changes in fair value recognized in earnings in the periods prior to settlement. 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 2014:

(Thousands)
Net balance of derivative assets at September 30, 2012	$	2,741
Changes in fair value	665
Settlements	(1,415		)
Net balance of derivative assets at March 31, 2013	$	1,991

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 six months ended March 31, 2013, 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 $0.6 million on an annual basis. Portions of such increases may be offset through the application of PGA carrying costs. At March 31, 2013, Laclede Gas had fixed-rate long-term debt totaling $440 million. Additionally, Laclede Group had fixed-rate long-term debt totaling $25 million. While these long-term debt issues are fixed-rate, they are subject to changes in fair value as market interest rates change. However, increases or decreases in fair value would impact earnings and cash flows only if the Company 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 its long-term debt would typically be deferred as regulatory assets or regulatory liabilities and amortized over a future period.

The Company has entered into certain interest rate swap transactions to protect itself against adverse movements in interest rates associated with its anticipated issuance of long-term debt to fund the acquisition of MGE. Refer to Note 7, Derivative Instruments and Hedging Activities, of the Notes to Consolidated Financial Statements for additional details on these interest rate swap transactions.

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.

43

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 42 of this report.

Item 4. Controls and Procedures

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

There have been no changes in our internal control over financial reporting that occurred during our second fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting. However, as management has not yet completed all of its testing of the operating effectiveness of all controls related to a significant system implementation that occurred earlier in the year, it will continue to evaluate the operating effectiveness of key controls during subsequent periods.

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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 adverse effect on the consolidated financial position or results of operations 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, 2012.

RISKS RELATED TO THE COMPANY'S ACQUISITION AGREEMENTS WITH SOUTHERN UNION COMPANY AND ALGONQUIN POWER & UTILITIES CORP.

The transactions may not be completed or may be approved subject to unfavorable regulatory conditions, which could adversely affect anticipated benefits and/or Laclede Group's business, financial condition, results of operations and/or stock price.

On December 14, 2012, Laclede Group, through two newly formed wholly owned subsidiaries, Plaza Missouri Acquisition, Inc. (Plaza Missouri) and Plaza Massachusetts Acquisition, Inc. (Plaza Massachusetts), entered into purchase and sale agreements to acquire from SUG substantially all of the assets and liabilities of MGE and NEG. Subsequently, on January 11, 2013, the Company and Plaza Missouri, with consent of SUG, entered into an agreement with Laclede Gas to assign the MGE agreement to Laclede Gas. On February 11, 2013, the Company announced that it entered into an agreement with Algonquin Power & Utilities Corp. (APUC) that will allow an APUC subsidiary, through its acquisition of the stock of Plaza Massachusetts, to acquire the Company's rights to purchase the assets of NEG, subject to certain approvals and conditions. However, the Company remains obligated to acquire NEG in the event that APUC is not able to satisfy all conditions to closing on or before October 14, 2013, although the Company believes this scenario would be unlikely. The Company's agreement with APUC is not expected to impact the MGE transaction. Nonetheless, there can be no assurance that APUC will be able to satisfy all of the required conditions on or before this date. In order to complete the transactions, the Company must obtain approvals from the Missouri Public Service Commission and the Massachusetts Department of Public Utilities. These governmental agencies could seek to block or challenge the acquisitions or could impose restrictions they deem necessary or desirable in the public interest as a condition to approving the acquisitions. There can be no assurance as to the receipt or timing of these approvals. The acquisition agreements require the Company to use its reasonable best efforts to obtain these approvals, which may include conditions or restrictions that could have an adverse effect on the anticipated benefits of the acquisitions or on the Company's business, financial condition or results of operations. In addition, if these approvals are not received, or they are not received on terms that satisfy the conditions set forth in the acquisition agreements, then the Company will not be obligated to complete the transaction. Because the closing of each acquisition is conditioned upon the closing of the other, a delay by one regulatory agency may delay both acquisitions.

In addition, the acquisition agreements contain other customary closing conditions which may not be satisfied or waived or may take longer than anticipated to satisfy. The pending transaction subjects Laclede Group to a number of additional risks, including the following:

• the Company's estimate of the costs to complete the acquisitions and the operating performance after the acquisitions close may vary significantly from actual results;

• both before and after the closing of the acquisitions, the attention of management may be diverted to the acquisitions and subsequent integration of MGE rather than to current operations or the pursuit of other opportunities that could be beneficial to the Company;

• the potential loss of key employees of the Company or of MGE or NEG who may be uncertain about their future roles if and when the acquisitions are completed; and

• the trading price of Laclede Group's common stock may decline to the extent that the current market price reflects a market assumption that the transaction will be completed.

45

The purchase and sale agreements contain certain termination rights for both the Company and SUG, including, among others, the right to terminate if the transactions are not completed by October 14, 2013 (subject to up to four 30-day extensions under certain circumstances related to obtaining required regulatory approvals). In the event that SUG terminates the MGE acquisition agreement as a result of the failure of Laclede Group to obtain financing, the Company may be required to pay SUG a "reverse break up" fee of $73.1 million, which amount will operate as liquidated damages and a cap on such liability for such breach.

The occurrence of any of these events individually or in combination could have a material adverse effect on the Company's business, financial condition or results of operations or the trading price of its common stock.

Laclede Group expects to issue significant debt and equity capital in order to provide permanent financing for the acquisition of MGE in lieu of and/or to refund borrowings under the bridge loan facility, and, as a result, the Company is subject to market risks including market demand for equity and debt offerings, equity price changes, and interest rate volatility, adverse impacts on its credit ratings and dilution of its common stock.

In connection with the acquisition agreements, Laclede Group has obtained a commitment from Wells Fargo Bank, National Association and various other banks for a syndicated $1.020 billion bridge loan facility, which may be used to finance a significant portion of the acquisitions and pay related fees and expenses in the event that permanent financing is not in place at the time of the closing of the acquisitions. The permanent financing is anticipated to include a mix of long-term debt of Laclede Group and/or Laclede Gas and common equity of Laclede Group, and, depending on market conditions, may include other instruments such as convertible debt, preferred shares, or term loans.

Although the Company and its advisers believe they have taken prudent steps to position the Company and its subsidiaries for successful capital raises, there can be no assurance as to the ultimate cost or availability of permanent financing.

Among other risks, the planned increase in indebtedness may:

• make it more difficult for Laclede Group to pay or refinance its debts as they become due during adverse economic and industry conditions;

• limit the Company's flexibility to pursue other strategic opportunities or react to changes in its business and the industry in which it operates and, consequently, place it at a competitive disadvantage to competitors with less debt;

• require an increased portion of the Company's cash flows from operations of Laclede Group and Laclede Gas to be used for debt service payments, thereby reducing the availability of its cash flow to fund working capital, capital expenditures, dividend payments and other general corporate purposes;

• result in a downgrade in the credit rating of Laclede Group's or Laclede Gas' indebtedness, which could limit their ability to borrow additional funds or increase the interest rates applicable to their indebtedness;

• result in higher interest expense in the event of increases in market interest rates for both long-term debt as well as short-term commercial paper or bank loans at variable rates;

• reduce the amount of credit available to support hedging activities; and

• require that additional terms, conditions or covenants be placed on the Company.

Among other risks, the planned issuance of additional equity by Laclede Group may:

• be dilutive to Laclede Group's existing shareholders and earnings per share;

• impact the Company's capital structure and cost of the capital;

• be adversely impacted by movements in the overall equity markets and/or the utility or natural gas utility industry sectors of that market, which could impact the offering price of the Company's new equity or necessitate the use of other equity or equity-like instruments such as preferred stock, convertible preferred shares, or convertible debt; and

• impact Laclede Group's ability to meet its current and future dividend obligations.

In addition, in order to maintain investment-grade credit ratings, Laclede Group may consider it appropriate to reduce the amount of indebtedness outstanding following the acquisitions. This may be accomplished in several ways, including issuing additional shares of common stock or securities convertible into shares of common stock, reducing discretionary uses of cash or a combination of these and other measures. The specific measures that management may ultimately decide to use to maintain or improve its credit ratings and their timing, will depend upon a number of factors, including market conditions and forecasts at the time those decisions are made.

46

The acquisition of MGE and associated costs and integration efforts may adversely affect the Company's business, financial condition or results of operations, which may negatively affect the market price of Laclede Group's common shares.

While management currently anticipates that the acquisition of MGE will be neutral to the Company's earnings per share in the first full year following their completion and accretive thereafter, this expectation is based on preliminary estimates which may materially change. Laclede Group may encounter additional transaction and integration-related costs, may fail to realize all of the anticipated benefits of the acquisitions or be subject to other factors that affect those preliminary estimates.

The process of integrating the operations of MGE could cause an interruption of, or loss of momentum in, the activities of one or more of those businesses and the possible loss of key personnel. The diversion of management's attention and any delays or difficulties encountered in connection with the transaction and the integration of the companies' operations could have an adverse effect on the business, results of operations, financial condition or prospects of Laclede Group after the acquisitions are ultimately consummated.

The Company expects to incur costs associated with combining the operations of the companies, as well as transaction fees and other costs related to the transaction. The Company also will incur integration costs in connection with the acquisitions and management is in the early stages of assessing the magnitude of these costs and additional unanticipated costs may be incurred in the integration of the businesses.

Any of these factors could cause a decrease in the price of Laclede Group's common shares.

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

During the quarter ended March 31, 2013, 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 Purchases	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
January 1, 2013 – January 31, 2013	154	$38.56	—	—
February 1, 2013 – February 28, 2013	—	—	—	—
March 1, 2013 – March 31, 2013	—	—	—	—
Total	154	—	—	—

Item 6. Exhibits

(a) See Exhibit Index

47

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:	April 30, 2013	By:	/s/ Steven P. Rasche
			Steven P. Rasche
			Senior Vice President, Finance and Accounting
			(Authorized Signatory and Principal Accounting Officer)

48

INDEX TO EXHIBITS

Exhibit No.
4.1		Thirty-First Supplemental Indenture dated as of March 15, 2013
10.1		First Amendment to Loan Agreement, dated as of January 16, 2013, among The Laclede Group, Inc. and the several banks parties thereto, including Wells Fargo Bank, National Association as administrative agent, filed as Exhibit 10.1 to Form 8-K filed January 18, 2013
10.2		First Amendment to Loan Agreement, dated as of January 16, 2013, among Laclede Gas Company and the several banks parties thereto, including Wells Fargo Bank, National Association as administrative agent, filed as Exhibit 10.2 to Form 8-K filed January 18, 2013
10.3		Assignment and Assumption Agreement dated January 11, 2013, filed as Exhibit 99.1 to Form 8-K filed January 14, 2013
10.4		Consent dated January 11, 2013, filed as Exhibit 99.2 to Form 8-K filed January 14, 2013
10.5		Stock Purchase Agreement dated February 11, 2013, filed as Exhibit 2.1 to Form 8-K filed February 12, 2013
10.6		Consent Agreement dated February 11, 2013, filed as Exhibit 2.2 to Form 8-K filed February 12, 2013.
12	-	Ratio of Earnings to Fixed Charges.
31	-	CEO and CFO Certifications under Exchange Act Rule 13a – 14(a).
32	-	CEO and CFO Section 1350 Certifications.
101.INS	-	XBRL Instance Document. (1)
101.SCH	-	XBRL Taxonomy Extension Schema. (1)
101.CAL	-	XBRL Taxonomy Extension Calculation Linkbase. (1)
101.DEF	-	XBRL Taxonomy Definition Linkbase. (1)
101.LAB	-	XBRL Taxonomy Extension Labels Linkbase. (1)
101.PRE	-	XBRL Taxonomy Extension Presentation Linkbase. (1)

(1) Attached as Exhibit 101 to this Quarterly Report are the following documents formatted in extensible business reporting language (XBRL): (i) Document and Entity Information; (ii) unaudited Statements of Consolidated Income for the three and six months ended March 31, 2013 and 2012; (iii) unaudited Statements of Consolidated Comprehensive Income for the three and six months ended March 31, 2013 and 2012; (iv) unaudited Consolidated Balance Sheets at March 31, 2013, September 30, 2012 and March 31, 2012; (v) unaudited Statements of Consolidated Cash Flows for the three and six months ended March 31, 2013 and 2012, and (vi) Notes to the unaudited Consolidated Financial Statements. We also make available on our website the Interactive Data Files submitted as Exhibit 101 to this Quarterly Report. 

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EX-4.1

Exhibit 4.1

EXECUTION VERSION

LACLEDE GAS COMPANY

TO

UMB BANK & TRUST, N.A.

Trustee

______________________________

Thirty-First Supplemental Indenture

Dated as of March 15, 2013

______________________________

First Mortgage Bonds

3.00% Series due March 15, 20233.40% Series due March 15, 2028

103518066 v7

TABLE OF CONTENTS
			Page
Parties			1
Recitals			1
	Previous Indentures		1
	Identity of the Company		9
	Identity of Trustee		10
	Outstanding Bonds		10
	Form of Fully Registered Bond of 2023 Series		11
	Form of Fully Registered Bond of 2028 Series		15
	Form of Trustee's Certificate of Authentication.		19
	Compliance with legal requirements		19
Granting Clause			19
Exception Clause			20
Habendum Clause			21
Exceptions, Reservations, etc.			21
Grant in trust			21
Covenant Clause			21
ARTICLE I
DEFINITIONS
SECTION 1.1		Terms Defined by Reference	21
SECTION 1.2		Business Day	22
SECTION 1.3		Trustee	22
SECTION 1.4		Original Indenture	22
SECTION 1.5		First Supplemental Indenture	22
SECTION 1.6		Second Supplemental Indenture	22
SECTION 1.7		Third Supplemental Indenture	22
SECTION 1.8		Fourth Supplemental Indenture	22
SECTION 1.9		Fifth Supplemental Indenture	22
SECTION 1.10		Sixth Supplemental Indenture	22
SECTION 1.11		Seventh Supplemental Indenture	22
SECTION 1.12		Eighth Supplemental Indenture	23
SECTION 1.13		Ninth Supplemental Indenture	23
SECTION 1.14		Tenth Supplemental Indenture	23
SECTION 1.15		Eleventh Supplemental Indenture	23
SECTION 1.16		Twelfth Supplemental Indenture	23
SECTION 1.17		Thirteenth Supplemental Indenture	23
SECTION 1.18		Fourteenth Supplemental Indenture	23
SECTION 1.19		Fifteenth Supplemental Indenture	23
SECTION 1.20		Sixteenth Supplemental Indenture	23
SECTION 1.21		Seventeenth Supplemental Indenture	23
SECTION 1.22		Eighteenth Supplemental Indenture	23

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SECTION 1.23	Nineteenth Supplemental Indenture	23
SECTION 1.24	Twentieth Supplemental Indenture	24
SECTION 1.25	Twenty-First Supplemental Indenture	24
SECTION 1.26	Twenty-Second Supplemental Indenture	24
SECTION 1.27	Twenty-Third Supplemental Indenture	24
SECTION 1.28	Twenty-Fourth Supplemental Indenture	24
SECTION 1.29	Twenty-Fifth Supplemental Indenture	24
SECTION 1.30	Twenty-Sixth Supplemental Indenture	24
SECTION 1.31	Twenty-Seventh Supplemental Indenture	24
SECTION 1.32	Twenty-Eighth Supplemental Indenture	24
SECTION 1.33	Twenty-Ninth Supplemental Indenture	24
SECTION 1.34	Thirtieth Supplemental Indenture	24
SECTION 1.35	Mortgage	24
SECTION 1.36	Hereof, Hereunder, etc.	25
SECTION 1.37	2023 Series and 2028 Series	25
ARTICLE II
CREATION, DESCRIPTION, REGISTRATION, TRANSFER AND
EXCHANGE OF THE 2023 SERIES OF BONDS
SECTION 2.1	Creation and principal amount of the 2023 Series	25
SECTION 2.2	Date of Bonds	25
SECTION 2.3	Denominations, etc.	25
SECTION 2.4	Exchange of Bonds	25
SECTION 2.5	Registration of Bonds	26
SECTION 2.6	Temporary Bonds	26
SECTION 2.7	Payment of Defaulted Interest	26
SECTION 2.8	Transfers or Exchanges of Bonds called for redemption	26
SECTION 2.9	Restrictive Legend	26
ARTICLE III
REDEMPTION OF BONDS OF THE 2023 SERIES
SECTION 3.1	Circumstances in Which Redeemable	27
SECTION 3.2	Additional Circumstances in Which Redeemable	27
SECTION 3.3	Purchase of Bonds	29
SECTION 3.4	Notice of Intention to Redeem	29
SECTION 3.5	No Other Redemptions	29
ARTICLE IV
CREATION, DESCRIPTION, REGISTRATION, TRANSFER AND
EXCHANGE OF THE 2028 SERIES OF BONDS
SECTION 4.1	Creation and Principal Amount of the 2028 Series	29

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SECTION 4.2	Date of Bonds	29
SECTION 4.3	Denominations, etc.	29
SECTION 4.4	Exchange of Bonds	30
SECTION 4.5	Registration of Bonds	30
SECTION 4.6	Temporary Bonds	30
SECTION 4.7	Payment of Defaulted Interest	30
SECTION 4.8	Transfers or Exchanges of Bonds Called for Redemption	31
SECTION 4.9	Restrictive Legend	31
ARTICLE V
REDEMPTION OF BONDS OF THE 2028 SERIES
SECTION 5.1	Circumstances in Which Redeemable	31
SECTION 5.2	Additional Circumstances in Which Redeemable	31
SECTION 5.3	Purchase of Bonds	33
SECTION 5.4	Notice of Intention to Redeem	33
SECTION 5.5	No Other Redemptions	33
ARTICLE VI
PARTICULAR COVENANTS OF THE COMPANY
SECTION 6.1	Restrictions as to Dividends	33
SECTION 6.2	Earnings Requirements for Additional Bonds	34
SECTION 6.3	Postponement of Interest	36
SECTION 6.4	Information as to Company	36
ARTICLE VII
COMPANY'S RESERVATION OF RIGHTS
SECTION 7.1	Company's Reservation of Rights	36
ARTICLE VIII
MISCELLANEOUS
SECTION 8.1	Provisions Required by Trust Indenture Act of 1939 to Control	38
SECTION 8.2	Acceptance of Trust	38
SECTION 8.3	This Indenture Part of Original Indenture	38
SECTION 8.4	Execution in Any Number of Counterparts	38
SECTION 8.5	Date of Execution	38

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THIRTY-FIRST SUPPLEMENTAL INDENTURE, dated as of the 15^th day of March, 2013 between LACLEDE GAS COMPANY, a corporation duly organized and existing under the laws of the State of Missouri, having its principal place of business at 720 Olive Street, St. Louis, Missouri 63101, hereinafter sometimes called the “Company,” party of the first part, and UMB BANK & TRUST, N.A., a national banking association organized under the laws of the United States, having its principal place of business and corporate trust office at Two South Broadway, St. Louis, Missouri 63102, hereinafter sometimes called the “Trustee,” party of the second part.

WHEREAS, there have heretofore been duly executed and delivered the following four indentures between the Company and Mississippi Valley Trust Company, to-wit:

(a)An indenture of mortgage and deed of trust, hereinafter sometimes called the “Original Indenture,” dated as of February 1, 1945, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 6324 at Page 93 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 2078 at Page 12 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 294 at Page 399 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 434 at Page 480 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 551 at Page 593 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 198 at Page 629 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 77 at Page 1 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 224 at Page 451 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 503 at Page 606 and is filed in the office of the Secretary of State of Missouri under filing number 26,557 and is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2590088; and

(b)A supplemental indenture, hereinafter sometimes called the “First Supplemental Indenture,” dated as of December 1, 1946, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 6562 at Page 528, and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 2268 at Page 273; and

(c)A supplemental indenture, hereinafter sometimes called the “Second Supple-mental Indenture,” dated as of March 15, 1948, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 6687 at Page 467, and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 2327 at Page 357; and

(d)A supplemental indenture, hereinafter sometimes called the “Third Supplemental Indenture,” dated as of April 1, 1951, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 7079 at Page 125 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 2869 at Page 275; and

WHEREAS, there have been heretofore duly executed and delivered four indentures between the Company and Mercantile Trust Company, to-wit:

(a)A supplemental indenture, hereinafter sometimes called the “Fourth Supple-mental Indenture,” dated as of December 1, 1954, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 7458 at Page 400 and in the office of the

103518066 v7

Recorder of Deeds of St. Louis County, Missouri, in Book 3342 at Page 34 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 294 at Page 477 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 434 at Page 574 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 552 at Page 1 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 198 at Page 721 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 77 at Page 183 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 224 at Page 632 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 507 at Page 1 and is filed in the office of the Secretary of State of Missouri under filing number 26,558; and

(b)A supplemental indenture, hereinafter sometimes called the “Fifth Supplemental Indenture,” dated as of May 1, 1957, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 7731 at Page 152 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 3766 at Page 1 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 294 at Page 494 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 434 at Page 611 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 552 at Page 38 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 199 at Page 1 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 77 at Page 220 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 226 at Page 1 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 507 at Page 38 and is filed in the office of the Secretary of State of Missouri under filing number 26,559; and

(c)A supplemental indenture, hereinafter sometimes called the “Sixth Supplemental Indenture,” dated as of July 1, 1960, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 8087 at Page 55 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 4348 at Page 1 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 294 at Page 535 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 434 at Page 651 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 552 at Page 78 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 199 at Page 22 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 77 at Page 260 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 226 at Page 42 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 507 at Page 62 and is filed in the office of the Secretary of State of Missouri under filing number 26,560; and

(d)A supplemental indenture, hereinafter sometimes called the “Seventh Supple-mental Indenture,” dated as of June 1, 1964, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 8506 at Page 215 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 5410 at Page 399 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 342 at Page 2 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 434 at Page 697 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 552 at Page 124 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 199 at Page 46 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 77 at Page 306 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 226 at Page 89 and in

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the office of the Recorder of Deeds of Butler County, Missouri, in Book 507 at Page 90 and is filed in the office of the Secretary of State of Missouri under filing number 26,561; and

WHEREAS, there have been heretofore duly executed and delivered eight indentures between the Company and Mercantile Trust Company National Association, to-wit:

(a)A supplemental indenture, hereinafter sometimes called the “Eighth Supple-mental Indenture,” dated as of April 15, 1966, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 8678 at Page 1 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 5949 at Page 450 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 361 at Page 148 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 434 at Page 746 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 552 at Page 172 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 199 at Page 71 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 77 at Page 354 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 226 at Page 138 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 507 at Page 118 and is filed in the office of the Secretary of State of Missouri under filing number 28,645; and

(b)A supplemental indenture, hereinafter sometimes called the “Ninth Supplemental Indenture,” dated as of May 1, 1968, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 8834 at Page 213 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 6323 at Page 1904 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 389 at Page 888 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 498 at Page 408 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 434 at Page 790 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 552 at Page 216 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 199 at Page 94 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 77 at Page 398 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 226 at Page 183 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 507 at Page 145 and is filed in the office of the Secretary of State of Missouri under filing number 87,403; and

(c)A supplemental indenture, hereinafter sometimes called the “Tenth Supplemental Indenture,” dated as of May 15, 1970, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 8988 at Page 52 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 6456 at Page 132 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 396 at Page 560 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 554 at Page 79 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 434 at Page 829 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 552 at Page 255 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 199 at Page 114 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 77 at Page 436 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 226 at Page 223 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 507 at Page 168 and is filed in the office of the Secretary of State of Missouri under filing number 154,857; and

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(d)A supplemental indenture, hereinafter sometimes called the “Eleventh Supple-mental Indenture,” dated as of March 15, 1972, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 9133 at Page 4 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 6577 at Page 1993 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 401 at Page 706 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 620 at Page 157 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 435 at Page 23 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 199 at Page 210 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 552 at Page 640 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 226 at Page 282 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 78 at Page 1 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 507 at Page 265 and is filed in the office of the Secretary of State of Missouri under filing number 234,221; and

(e)A supplemental indenture, hereinafter sometimes called the “Twelfth Supple-mental Indenture,” dated as of March 15, 1974, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 40M at Page 1 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 6721 at Page 91 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 407 at Page 888 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 677 at Page 1445 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 465 at Page 976 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 210 at Page 255 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 598 at Page 683 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 237 at Page 1 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 84 at Page 117 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 535 at Page 540 and in the office of the Recorder of Deeds of Beckham County, Oklahoma, in Book 127 at Page 149 and in the office of the County Clerk of Wheeler County, Texas, in Trust Vol. 58 at Page 731 and is filed in the office of the Secretary of State of Missouri under filing number 333,360; and

(f)A supplemental indenture, hereinafter sometimes called the “Thirteenth Supple-mental Indenture,” dated as of June 1, 1975, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 70M at Page 2061 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 6796 at Page 1447 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 411 at Page 9 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 704 at Page 1739 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 481 at Page 292 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 124 at Page 225 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 624 at Page 359 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 242 at Page 234 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 86 at Pages 483-532 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 547 at Page 300 and in the office of the Recorder of Deeds of Beckham County, Oklahoma, in Book 130 at Page 416 and in the office of the County Clerk of Wheeler County, Texas, in Trust Vol. 59 at Page 649 and in the office of the Clerk of Court for Sabine Parish, Louisiana, under Registry No. 227328 in Mtg. Book 108 at Page 478 and in the office of the Clerk of Court for

4

DeSoto Parish, Louisiana, under Registry No. 378628 in Mtg. Book 115 at Page 803 and in the office of the Clerk of Court for St. Mary Parish, Louisiana, under Registry No. 124894 in Mtg. Book 343 at Page 293 and in the office of the Clerk of Court for Red River Parish, Louisiana, under Registry No. 128419 in Mtg. Book 75 at Page 546 and is filed in the office of the Secretary of State of Missouri under filing number 397,857; and

(g)A supplemental indenture, hereinafter sometimes called the “Fourteenth Supple-mental Indenture,” dated as of October 26, 1976, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 108M at Page 131 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 6907 at Page 1970 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 416 at Page 192 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 745 at Page 40 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 507 at Page 669 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 241 at Page 279 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 654 at Page 132 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 248 at Page 795 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 89 at Pages 694-700 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 565 at Page 57 and in the office of the Recorder of Deeds of Beckham County, Oklahoma, in Book 315 at Page 146 and in the office of the County Clerk of Wheeler County, Texas, in the Deed Records Vol. 260 at Page 991 and in the office of the Clerk of Court for Sabine Parish, Louisiana, under Registry No. 233001 in Mtg. Book 114 at Page 208 and in the office of the Clerk of Court for DeSoto Parish, Louisiana, under Registry No. 389929 in Mtg. Book 122 at Page 15 and in the office of the Clerk of Court for St. Mary Parish, Louisiana, under Registry No. 129850 in Mtg. Book 360 at Page 593 and in the office of the Clerk of Court for Red River Parish, Louisiana, under Registry No. 131795 in Mtg. Book 79 at Page 21 and is filed in the office of the Secretary of State of Missouri under filing number 479,397 and is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2590089; and

(h)A supplemental indenture, hereinafter sometimes called the “Fifteenth Supple-mental Indenture,” dated as of July 15, 1979, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 202M at Page 1288 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 7181 at Page 23 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 430 at Page 273 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 846 at Page 880 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 580 at Page 278 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 285 at Page 93 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 722 at Page 57 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 262 at Pages 709-770 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 98 at Pages 720-781 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 597 at Page 661 and in the office of the County Clerk of Beckham County, Oklahoma, in Misc. Record Book 385 at Page 230 and in the office of the County Clerk of Roger Mills County, Oklahoma, in Book 273 at Pages 54-116 and in the office of the County Clerk of Blaine County, Oklahoma, in Book 325 Misc. Page 1 and in the office of the County Clerk of Wheeler County, Texas, in Deed of Trust Records, Vol. 64 at Page 707 and in the office of the County Clerk of

5

Lipscomb County, Texas, in the Deed of Trust Records, Vol. 196 at Page 607 and in the office of the County Clerk of Roberts County, Texas, in the Deed of Trust Records, Vol. 30 at Page 45 and in the office of the County Clerk of Hemphill County, Texas, in the Deed of Trust Records, Vol. 59 at Page 428 and in the office of the Clerk of the Court for St. Mary Parish, Louisiana, under Registry No. 141319 in Mtg. Book 402 at Page 2 and in the office of the Clerk of the Court for the DeSoto Parish, Louisiana, under Registry No. 417237 in Mtg. Book 136 at Page 524 and in the office of the Clerk of the Court for Sabine Parish, Louisiana, under Registry No. 246026 in Mtg. Book 128 at Page 86 and in the office of the Clerk of the Court for Red River Parish, Louisiana, under Registry No. 141470 in Mtg. Book 87 at Page 619 and in the office of the Clerk of the Court for Terrebonne Parish, Louisiana, under Registry No. 602396 and is filed in the office of the Secretary of State of Missouri under Document Number 667303; and

WHEREAS, there have been heretofore duly executed and delivered two indentures between the Company and Mercantile Bank National Association, to-wit:

(a)A supplemental indenture, hereinafter sometimes called the “Sixteenth Supple-mental Indenture,” dated as of May 1, 1986, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book M-529 at Page 655 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 7902 at Page 1138 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 573 at Page 2 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 1080 at Page 1577 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 197 at Page 1 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 407 at Page 137 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 894 at Page 138 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 293 at Page 797 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 116 at Page 589 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 669 at Page 228 and in the office of the County Clerk of Roger Mills County, Oklahoma, in Book 807 at Page 120 and in the office of the County Clerk of Wheeler County, Texas, in Deed of Trust Records, Vol. 91 at Page 191, and in Deed Records, Vol. 348 at Page 69 and in the office of the Secretary of State of Texas under Document Number 131214 and is filed in the office of the Secretary of State of Missouri under Document Number 1322775; and

(b)A supplemental indenture, hereinafter sometimes called the “Seventeenth Supplemental Indenture,” dated as of May 15, 1988, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book M-669 at Page 258 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 8315 at Page 902 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 676 at Page 449 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 1212 at Page 1948 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 396 at Page 1987 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 459 at Page 289 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 962 at Page 8 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 303 at Page 527 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 123 at Page 243 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 691 at Page 620 and in the office of the County Clerk of Roger Mills County, Oklahoma, in Book 973 at Page 1 and in the office of the County Clerk of Wheeler County, Texas, in Deed

6

of Trust Records, Vol. 91 at Page 234, and in Deed Records, Vol. 369 at Page 386 and in the office of the Secretary of State of Texas under Document Number 86131214 and is filed in the office of the Secretary of State of Missouri under Document Number 1596374 and is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2590090; and

WHEREAS, there have been heretofore duly executed and delivered five indentures between the Company and Mercantile Bank of St. Louis National Association, to-wit:

(a)A supplemental indenture, hereinafter sometimes called the “Eighteenth Supple-mental Indenture,” dated as of November 15, 1989, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 762M at Page 1126 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 8646 at Page 2196 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 748 at Page 17 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 1294 at Page 631 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 442 at Page 14 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 498 at Page 13 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 1012 at Page 36 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 311 at Page 503 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 127 at Page 682 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 709 at Page 78 and in the office of the County Clerk of Roger Mills County, Oklahoma, in Book 1094 at Page 263 and in the office of the County Clerk of Wheeler County, Texas, in Deed of Trust Records, Vol. 93 at Page 630 and in the office of the Secretary of State of Texas under Document Number 252980 and is filed in the office of the Secretary of State of Missouri under Document Number 1798065 and is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2590091; and

(b)A supplemental indenture, hereinafter sometimes called the “Nineteenth Supple-mental Indenture,” dated as of May 15, 1991, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book 848 at Page 716 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 8983 at Page 1095 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 821 at Page 79 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 1370 at Page 1846 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 483 at Page 1909 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 541 at Page 82 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 1060 at Page 253 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 319 at Page 355 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 132 at Page 44 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 725 at Page 442 and in the office of the County Clerk of Roger Mills County, Oklahoma, in Book 1213 at Page 105, UCC Filing No. 135, and in the office of the County Clerk of Oklahoma County, Oklahoma, UCC Filing No. 023021, and in the office of the County Clerk of Wheeler County, Texas, in Deed of Trust Records, Vol. 96 at Page 96 and in Deed Records, Book 399 at Page 254, and in the office of the Secretary of State of Texas under Document Number 088153 and is filed in the office of the Secretary of State of Missouri under Document Number 1999268 and is filed

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in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2590092; and

(c)A supplemental indenture, hereinafter sometimes called the “Twentieth Supple-mental Indenture,” dated as of November 1, 1992, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book M945 at Page 1068 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 9494 at Page 423 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 937 at Page 144 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 1491 at Page 1289 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 543 at Page 2135 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 594 at Page 10 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 1121 at Page 458 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 326 at Page 888 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 137 at Page 166 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 747 at Page 72 and in the office of the Recorder of Deeds of Franklin County, Missouri, in Book 712 at Page 889 and in the office of the County Clerk of Roger Mills County, Oklahoma, in Book 1303 at Page 39, UCC Filing No. 296, and in the office of the County Clerk of Oklahoma County, Oklahoma, UCC Filing No. 056514, and in the office of the County Clerk of Wheeler County, Texas, in Deed of Trust Records, Book 98 at Page 88 and in Deed Records, Book 409 at Page 589, and in the office of the Secretary of State of Texas under Document Number 212435 and is filed in the office of the Secretary of State of Missouri under Document Number 2188520 and is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2590093; and

(d)A supplemental indenture, hereinafter sometimes called the “Twenty-First Supplemental Indenture,” dated as of May 1, 1993, which is recorded in the office of the Recorder of Deeds of the City of St. Louis, Missouri, in Book M982 at Page 0356 and in the office of the Recorder of Deeds of St. Louis County, Missouri, in Book 9701 at Page 797 and in the office of the Recorder of Deeds of Boone County, Missouri, in Book 979 at Page 722 and in the office of the Recorder of Deeds of St. Charles County, Missouri, in Book 1542 at Page 1449 and in the office of the Recorder of Deeds of Jefferson County, Missouri, in Book 567 at Page 2217 and in the office of the Recorder of Deeds of Ste. Genevieve County, Missouri, in Book 610 at Page 136 and in the office of the Recorder of Deeds of St. Francois County, Missouri, in Book 1142 at Page 84 and in the office of the Recorder of Deeds of Iron County, Missouri, in Book 328 at Page 508 and in the office of the Recorder of Deeds of Madison County, Missouri, in Book 139 at Page 361 and in the office of the Recorder of Deeds of Butler County, Missouri, in Book 753 at Page 328 and in the office of the Recorder of Deeds of Franklin County, Missouri, in Book 743 at Page 638 and in the office of the County Clerk of Roger Mills County, Oklahoma, in Book 1337 at Page 10, UCC Filing No. 109, and in the office of the County Clerk of Oklahoma County, Oklahoma, UCC Filing No. 023874 and in the office of the County Clerk of Wheeler County, Texas, in Deed of Trust Records, Book 98 at Page 804 and in Deed Records, Book 413 at Page 387, and in the office of the Secretary of State of Texas under Document No. 086970 and is filed in the office of the Secretary of State of Missouri under Document No. 2259648 and is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2590094; and

8

(e)A supplemental indenture, hereinafter sometimes called the “Twenty-Second Supplemental Indenture,” dated as of November 15, 1995, which is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2604323; and

WHEREAS, there have been heretofore duly executed and delivered three indentures between the Company and State Street Bank and Trust Company of Missouri, N.A., to-wit:

(a)A supplemental indenture, hereinafter sometimes called the “Twenty-Third Supplemental Indenture,” dated as of October 15, 1997, which is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 2841222; and

(b)A supplemental indenture, hereinafter sometimes called the “Twenty-Fourth Supplemental Indenture,” dated as of June 1, 1999, which is filed in the office of the Secretary of State of Missouri pursuant to R.S.Mo. 443.451 under filing number 3039096; and

(c)A supplemental indenture, hereinafter sometimes called the “Twenty-Fifth Supplemental Indenture,” dated as of September 15, 2000, which is filed in the office of the Secretary of the State of Missouri pursuant to R.S.Mo. 443.451 under filing number 4088953; and

WHEREAS, there has been heretofore duly executed and delivered five supplemental indentures between the Company and UMB Bank & Trust, N.A., to-wit:

(a)A supplemental indenture, hereinafter sometimes called the “Twenty-Sixth Supplemental Indenture,” dated as of June 15, 2001, which is filed in the office of the Secretary of State of the State of Missouri pursuant to R.S.Mo. 443.451 under filing number 4178825; and

(b)A supplemental indenture, hereinafter sometimes called the “Twenty-Seventh Supplemental Indenture,” dated as of April 15, 2004, which is filed in the office of the Secretary of State of the State of Missouri pursuant to R.S.Mo. 443.451 under filing number 20040045002J; and

(c)A supplemental indenture, hereinafter sometimes called the “Twenty-Eighth Supplemental Indenture,” dated as of April 15, 2004, which is filed in the office of the Secretary of State of the State of Missouri pursuant to R.S.Mo. 443.451 under filing number 20040045001H; and

(d)A supplemental indenture, hereinafter sometimes called the “Twenty-Ninth Supplemental Indenture,” dated as of June 1, 2006, which is filed in the office of the Secretary of State of the State of Missouri pursuant to R.S.Mo. 443.451 under filing number 20060063448E; and

(e)A supplemental indenture, hereafter sometimes called the “Thirtieth Supplemental Indenture,” dated as of September 15, 2008, which is filed in the office of the Secretary of State of the State of Missouri pursuant to R.S.Mo. 443.451 under filing number 20080102574M; and

WHEREAS, the Company is the same corporation as is designated in the Original and First and Second Supplemental Indentures as The Laclede Gas Light Company, which was the

9

Company’s corporate name, but before the date of the Third Supplemental Indenture its corporate name was duly changed to, and now is, Laclede Gas Company; and

WHEREAS, UMB Bank & Trust, n.a., the party of the second part to this Thirty-First Supplemental Indenture, is the present Trustee under the Original Indenture, being the successor to State Street Bank and Trust Company of Missouri, N. A., which was the successor to Mercantile Bank of St. Louis National Association (from which State Street Bank and Trust Company of Missouri, N.A., acquired certain corporate trust assets), which was the successor to Mercantile Bank National Association, which was the successor to Mercantile Trust Company National Association, which was the successor to Mercantile Trust Company (which in turn was the corporation resulting from a consolidation on August 31, 1951, to which Mississippi Valley Trust Company, the original Trustee, was a party); and

WHEREAS, there are now outstanding under the Twenty-Third Supplemental Indenture, First Mortgage Bonds of the 6 1/2% Series due October 15, 2012; under the Twenty-Fourth Supplemental Indenture, First Mortgage Bonds of the 7% Series due June 1, 2029; under the Twenty-Fifth Supplemental Indenture, First Mortgage Bonds of the 7.90% Series due September 15, 2030; under the Twenty-Seventh Supplemental Indenture, First Mortgage Bonds of the 5½% Series due May 1, 2019; under the Twenty-Eighth Supplemental Indenture, First Mortgage Bonds of the 6% Series due May 1, 2034; under the Twenty-Ninth Supplemental Indenture, First Mortgage Bonds of the 6.15% Series due June 1, 2036; and under the Thirtieth Supplemental Indenture, First Mortgage Bonds of the 6.35% Series due October 15, 2038;but all bonds of the twenty two series provided for respectively by the First, Second, Third, Fourth, Fifth, Sixth, Seventh, Eighth, Ninth, Tenth, Eleventh, Twelfth, Thirteenth, Fifteenth, Sixteenth, Seventeenth, Eighteenth, Nineteenth, Twentieth, Twenty-First, Twenty-Second and Twenty-Sixth Supplemental Indentures and the First Mortgage Bonds of the 3 1/2% Series issued under the Original Indenture have ceased to be outstanding; and

WHEREAS, the Company desires to create two new series of bonds under the Mortgage to be designated as “First Mortgage Bonds, 3.00% Series due March 15, 2023” (hereinafter sometimes referred to as the “2023 Series”), for an aggregate principal amount of $55,000,000, and “First Mortgage Bonds, 3.40% Series due March 15, 2028” (hereinafter sometimes referred to as the “2028 Series”), for an aggregate principal amount of $45,000,000, in each case to be issued as fully registered bonds without coupons, the definitive bonds (certain of the provisions of which may be printed on the reverse side thereof) and the Trustee’s certificate of authentication thereof to be substantially in the following forms, respectively:

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(FORM OF FULLY REGISTERED BOND OF 2023 SERIES)

THIS SECURITY (OR ITS PREDECESSOR) WAS ORIGINALLY ISSUED IN A TRANSACTION EXEMPT FROM REGISTRATION UNDER SECTION 5 OF THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED, AND THIS SECURITY MAY NOT BE OFFERED, SOLD OR OTHERWISE TRANSFERRED IN THE ABSENCE OF SUCH REGISTRATION OR AN APPLICABLE EXEMPTION THEREFROM.

LACLEDE GAS COMPANYFIRST MORTGAGE BOND,3.00% Series due March 15, 2023

No.____________ $_________________

LACLEDE GAS COMPANY, a corporation of the State of Missouri (hereinafter called “the Company”), for value received hereby promises to pay to or registered assigns, at the office or agency of the Company in the Borough of Manhattan, The City of New York, or at the option of the registered owner hereof at the office or agency of the Company in the City of St. Louis, State of Missouri, _____________________ Dollars on the fifteenth day of March, 2023 (or upon earlier redemption), by check or draft (or as otherwise provided herein) in such coin or currency of the United States of America as at the time of payment shall be legal tender for public and private debts, and to pay to the registered owner hereof by check or draft (or as otherwise provided herein) interest thereon from and including March 15, 2013 or from the fifteenth day of March or September next preceding the date of this bond to which date interest has been paid or duly provided for (or, if this bond is dated any date after the record date for any interest payment date and on or before such interest payment date, then from such interest payment date), at the rate of 3.00% per annum, in like coin or currency at either of said offices or agencies at the option of the registered owner hereof, on March 15 and September 15 in each year, until the Company's obligation with respect to the payment of such principal shall have been discharged. If any interest payment date or any date of maturity or redemption of principal of this bond falls on a day that is not a Business Day (as defined below), principal and/or interest payable on such date will be paid on the succeeding Business Day with the same force and effect as if it were paid on the date such payment was due, and, in the case of the date of maturity or redemption of principal only, interest will accrue on the amount so payable for the period from and after such date to such succeeding Business Day. “Business Day” means any day other than a Saturday, Sunday, or other day on which commercial banks are authorized or required by law, regulation, or executive order to close in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri or on which the corporate trust office of the Trustee is closed for business. The interest so payable on any March 15 or September 15 will, subject to certain exceptions provided in the Mortgage hereinafter mentioned, be paid to the person in whose name this bond is registered at the close of business on the record date, which shall be March 1 or September 1, as the case may be, next preceding such interest payment date (whether or not a Business Day). If a registered owner of an aggregate principal amount in excess of $100,000 of the bonds so requests, payments of principal and interest to that registered owner shall be made by electronic transfer to an account at a commercial bank or savings institution located in the continental United States designated in writing by such registered owner. Any

11

such request must be made in writing to the Company and UMB Bank & Trust, n.a. (hereinafter sometimes referred to as the “Trustee”) at least 10 days in advance of such payment and must specify the name and address of the receiving bank, its ABA routing number, and the account name and number to receive the electronic transfer.

This bond is one of an issue of bonds of the Company, issuable in series, and is one of a series known as its First Mortgage Bonds, 3.00% Series due March 15, 2023 (hereinafter referred to as the “2023 Series”), all bonds of all series issued and to be issued under and equally secured (except in so far as any sinking or other fund established in accordance with the provisions of the Mortgage hereinafter mentioned may afford additional security for the bonds of any particular series) by a Mortgage and Deed of Trust (hereinafter referred to as the “Original Indenture”) dated as of February 1, 1945, executed by the Company to Mississippi Valley Trust Company, which was succeeded through consolidation by Mercantile Trust Company, which was succeeded by Mercantile Trust Company National Association, which was succeeded by Mercantile Bank National Association, which was succeeded by Mercantile Bank of St. Louis National Association, which was succeeded by State Street Bank and Trust Company of Missouri, N.A., which in turn was succeeded by UMB Bank & Trust, n.a., as Trustee, and indentures supplemental thereto, including the Thirty-First Supplemental Indenture thereto dated as of March 15, 2013 (hereinafter referred to as the “Thirty-First Supplemental Indenture”), said Mortgage and Deed of Trust as supplemented being herein called the “Mortgage,” to which reference is made for a description of the property mortgaged and pledged, the nature and extent of the security, the rights of the owners of the bonds in respect thereof, the duties and immunities of the Trustee, and the terms and conditions upon which the bonds are secured. With the consent of the Company and to the extent permitted by and as provided in the Mortgage, the rights and obligations of the Company and/or of the owners of the bonds and/or coupons and/or the terms and provisions of the Mortgage and/or of any instruments supplemental thereto may be modified or altered by the affirmative vote of the owners of at least sixty-six and two-thirds percent (66 2/3%) in principal amount of the bonds affected by such modification or alteration (including the bonds of the 2023 Series, if so affected), then outstanding under the Mortgage (excluding bonds disqualified from voting by reason of the Company’s interest therein as provided in the Mortgage); provided that no such modification or alteration shall permit the extension of the maturity of the principal of this bond or the reduction in the rate of interest hereon or any other modification in the terms of payment of such principal or interest, or the creation of a lien on the mortgaged and pledged property ranking prior to or on a parity with the lien of the Mortgage or the deprivation of the owner hereof of a lien upon such property without the consent of the owner hereof, except that the owners of not less than seventy-five percent (75%) in principal amount of the bonds at any time outstanding under the Mortgage (including a like percent of the principal amount of the bonds of the 2023 Series, if any interest payment on bonds of the 2023 Series is to be affected) may consent on behalf of the owners of all bonds at any time outstanding to the postponement of any interest payment for a period not exceeding three years from its due date.

The bonds of the 2023 Series are redeemable prior to maturity, in whole or in part, upon the notice referred to below, and otherwise subject to the provisions of the Mortgage: (i) pursuant to paragraph (B) of Section 13.06 of the Original Indenture (having reference to the taking of all the mortgaged property by eminent domain and certain comparable contingencies) at 100% of the principal amount thereof, together with accrued interest thereon to the date fixed

12

for redemption; or (ii) pursuant to Section 3.2 of the Thirty-First Supplemental Indenture at a redemption price equal to 100% of the principal amount to be redeemed plus the Make-Whole Amount (as defined in the Thirty-First Supplemental Indenture) determined for the redemption date with respect to such principal amount, plus, in each case, accrued interest thereon to the date fixed for redemption without premium. The Company will give each holder of bonds of the 2023 Series written notice of each optional redemption under Section 3.2 of the Thirty-First Supplemental Indenture not less than thirty (30) days and not more than sixty (60) days prior to the date fixed for such redemption. Each such notice shall specify such redemption date (which shall be a Business Day), the aggregate principal amount of the bonds to be redeemed on such date, the principal amount of each bond held by such holder to be redeemed (determined in accordance with Section 3.2 of the Thirty-First Supplemental Indenture), and the interest to be paid on the redemption date with respect to such principal amount being redeemed, and shall be accompanied by a certificate of the chief financial officer, principal accounting officer, treasurer or controller of the Company (each a “Senior Financial Officer”) as to the estimated Make-Whole Amount due in connection with such redemption (calculated as if the date of such notice were the date of the redemption), setting forth the details of such computation. Two Business Days prior to such redemption, the Company shall deliver to each holder of bonds of the 2023 Series a certificate of a Senior Financial Officer specifying the calculation of such Make-Whole Amount as of the specified redemption date. Except as set forth above, the bonds of the 2023 Series are not redeemable prior to March 15, 2023.

The principal hereof and the interest accrued hereon may be declared or may become due on the conditions, in the manner, and at the time set forth in the Mortgage, upon the occurrence of a completed default as in the Mortgage provided.

At the option of the registered owner, any bonds of the 2023 Series, upon surrender thereof at the office or agency of the Company in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri, together with a written instrument of transfer in form approved by the Company duly executed by the registered owner or his duly authorized attorney, shall, subject to the provisions of Section 2.05 of the Original Indenture, be exchangeable for a like aggregate amount of fully registered bonds of the same series of other authorized denominations.

This bond is transferable as prescribed in the Mortgage by the registered owner hereof in person, or by his duly authorized attorney, at the office or agency of the Company in the Borough of Manhattan, The City of New York, or in the City of St. Louis, upon surrender and cancellation of this bond and upon presentation of a written instrument of transfer, duly executed, with signature guaranteed by a signature guarantor that is a participant in a nationally recognized signature guaranty program, and upon payment, if the Company shall require it, of the transfer charges prescribed in the Mortgage, and thereupon, a new fully registered bond of the same series for a like principal amount will be issued to the transferee in exchange herefor as provided in the Mortgage. The Company and the Trustee may deem and treat the person in whose name this bond is registered as the absolute owner hereof for the purpose of receiving payment and for all other purposes.

No recourse shall be had for the payment of the principal of or of interest on this bond against any incorporator or any past, present or future subscriber to the capital stock, stockholder,

13

officer or director of the Company or of any predecessor or successor corporation, as such, either directly or through the Company or any predecessor or successor corporation, under any rule of law, statute or constitution or by the enforcement of any assessment or otherwise, all such liability of incorporators, subscribers, stockholders, officers and directors, as such, being released by the owner hereof by the acceptance of this bond and being likewise waived and released by the terms of the Mortgage.

Each holder of this bond will be deemed, by its acceptance hereof, to have (i) agreed to the confidentiality provisions set forth in Section 16 of the Bond Purchase Agreement dated as of August 3, 2012, between the Company and the purchasers of bonds of the 2023 Series listed in Schedule A thereto (the “Bond Purchase Agreement”) and (ii) made the representations set forth in Section 6.1 of the Bond Purchase Agreement.

This bond shall not become obligatory until UMB Bank & Trust, n.a., the Trustee under the Mortgage, or its successor thereunder, shall have signed the form of certificate endorsed hereon.

IN WITNESS WHEREOF, LACLEDE GAS COMPANY has caused this instrument to be signed in its name by its President or one of its Vice-Presidents, by his or her signature or a facsimile thereof, and a facsimile of its corporate seal to be imprinted hereon and attested by its Secretary or one of its Assistant Secretaries, by his or her signature or a facsimile thereof.

Dated	LACLEDE GAS COMPANY
	By
		President
ATTEST:
Secretary

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(FORM OF FULLY REGISTERED BOND OF 2028 SERIES)

THIS SECURITY (OR ITS PREDECESSOR) WAS ORIGINALLY ISSUED IN A TRANSACTION EXEMPT FROM REGISTRATION UNDER SECTION 5 OF THE UNITED STATES SECURITIES ACT OF 1933, AS AMENDED, AND THIS SECURITY MAY NOT BE OFFERED, SOLD OR OTHERWISE TRANSFERRED IN THE ABSENCE OF SUCH REGISTRATION OR AN APPLICABLE EXEMPTION THEREFROM.

LACLEDE GAS COMPANYFIRST MORTGAGE BOND,3.40% Series due March 15, 2028

No.____________ $_________________

LACLEDE GAS COMPANY, a corporation of the State of Missouri (hereinafter called “the Company”), for value received hereby promises to pay to or registered assigns, at the office or agency of the Company in the Borough of Manhattan, The City of New York, or at the option of the registered owner hereof at the office or agency of the Company in the City of St. Louis, State of Missouri, _____________________ Dollars on the fifteenth day of March, 2028 (or upon earlier redemption), by check or draft (or as otherwise provided herein) in such coin or currency of the United States of America as at the time of payment shall be legal tender for public and private debts, and to pay to the registered owner hereof by check or draft (or as otherwise provided herein) interest thereon from and including March 15, 2013 or from the fifteenth day of March or September next preceding the date of this bond to which date interest has been paid or duly provided for (or, if this bond is dated any date after the record date for any interest payment date and on or before such interest payment date, then from such interest payment date), at the rate of 3.40% per annum, in like coin or currency at either of said offices or agencies at the option of the registered owner hereof, on March 15 and September 15 in each year, until the Company's obligation with respect to the payment of such principal shall have been discharged. If any interest payment date or any date of maturity or redemption of principal of this bond falls on a day that is not a Business Day (as defined below), principal and/or interest payable on such date will be paid on the succeeding Business Day with the same force and effect as if it were paid on the date such payment was due, and, in the case of the date of maturity or redemption of principal only, interest will accrue on the amount so payable for the period from and after such date to such succeeding Business Day. “Business Day” means any day other than a Saturday, Sunday, or other day on which commercial banks are authorized or required by law, regulation, or executive order to close in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri or on which the corporate trust office of the Trustee is closed for business. The interest so payable on any March 15 or September 15 will, subject to certain exceptions provided in the Mortgage hereinafter mentioned, be paid to the person in whose name this bond is registered at the close of business on the record date, which shall be March 1 or September 1, as the case may be, next preceding such interest payment date (whether or not a Business Day). If a registered owner of an aggregate principal amount in excess of $100,000 of the bonds so requests, payments of principal and interest to that registered owner shall be made by electronic transfer to an account at a commercial bank or savings institution located in the continental United States designated in writing by such registered owner. Any

15

such request must be made in writing to the Company and UMB Bank & Trust, n.a. (hereinafter sometimes referred to as the “Trustee”) at least 10 days in advance of such payment and must specify the name and address of the receiving bank, its ABA routing number, and the account name and number to receive the electronic transfer.

This bond is one of an issue of bonds of the Company, issuable in series, and is one of a series known as its First Mortgage Bonds, 3.40% Series due March 15, 2028 (hereinafter referred to as the “2028 Series”), all bonds of all series issued and to be issued under and equally secured (except in so far as any sinking or other fund established in accordance with the provisions of the Mortgage hereinafter mentioned may afford additional security for the bonds of any particular series) by a Mortgage and Deed of Trust (hereinafter referred to as the “Original Indenture”) dated as of February 1, 1945, executed by the Company to Mississippi Valley Trust Company, which was succeeded through consolidation by Mercantile Trust Company, which was succeeded by Mercantile Trust Company National Association, which was succeeded by Mercantile Bank National Association, which was succeeded by Mercantile Bank of St. Louis National Association, which was succeeded by State Street Bank and Trust Company of Missouri, N.A., which in turn was succeeded by UMB Bank & Trust, n.a., as Trustee, and indentures supplemental thereto, including the Thirty-First Supplemental Indenture thereto dated as of March 15, 2013 (hereinafter referred to as the “Thirty-First Supplemental Indenture”), said Mortgage and Deed of Trust as supplemented being herein called the “Mortgage,” to which reference is made for a description of the property mortgaged and pledged, the nature and extent of the security, the rights of the owners of the bonds in respect thereof, the duties and immunities of the Trustee, and the terms and conditions upon which the bonds are secured. With the consent of the Company and to the extent permitted by and as provided in the Mortgage, the rights and obligations of the Company and/or of the owners of the bonds and/or coupons and/or the terms and provisions of the Mortgage and/or of any instruments supplemental thereto may be modified or altered by the affirmative vote of the owners of at least sixty-six and two-thirds percent (66 2/3%) in principal amount of the bonds affected by such modification or alteration (including the bonds of the 2028 Series, if so affected), then outstanding under the Mortgage (excluding bonds disqualified from voting by reason of the Company’s interest therein as provided in the Mortgage); provided that no such modification or alteration shall permit the extension of the maturity of the principal of this bond or the reduction in the rate of interest hereon or any other modification in the terms of payment of such principal or interest, or the creation of a lien on the mortgaged and pledged property ranking prior to or on a parity with the lien of the Mortgage or the deprivation of the owner hereof of a lien upon such property without the consent of the owner hereof, except that the owners of not less than seventy-five percent (75%) in principal amount of the bonds at any time outstanding under the Mortgage (including a like percent of the principal amount of the bonds of the 2028 Series, if any interest payment on bonds of the 2028 Series is to be affected) may consent on behalf of the owners of all bonds at any time outstanding to the postponement of any interest payment for a period not exceeding three years from its due date.

The bonds of the 2028 Series are redeemable, prior to maturity, in whole or in part, upon the notice referred to below, and otherwise subject to the provisions of the Mortgage: (i) pursuant to paragraph (B) of Section 13.06 of the Original Indenture (having reference to the taking of all the mortgaged property by eminent domain and certain comparable contingencies) at 100% of the principal amount thereof, together with accrued interest thereon to the date fixed

16

for redemption; or (ii) pursuant to Section 5.2 of the Thirty-First Supplemental Indenture at a redemption price equal to 100% of the principal amount to be redeemed plus the Make-Whole Amount (as defined in the Thirty-First Supplemental Indenture) determined for the redemption date with respect to such principal amount, plus, in each case, accrued interest thereon to the date fixed for redemption without premium. The Company will give each holder of bonds of the 2028 Series written notice of each optional redemption under Section 5.2 of the Thirty-First Supplemental Indenture not less than thirty (30) days and not more than sixty (60) days prior to the date fixed for such redemption. Each such notice shall specify such redemption date (which shall be a Business Day), the aggregate principal amount of the bonds to be redeemed on such date, the principal amount of each bond held by such holder to be redeemed (determined in accordance with Section 5.2 of the Thirty-First Supplemental Indenture), and the interest to be paid on the redemption date with respect to such principal amount being redeemed, and shall be accompanied by a certificate of the chief financial officer, principal accounting officer, treasurer or controller of the Company (each a “Senior Financial Officer”) as to the estimated Make-Whole Amount due in connection with such redemption (calculated as if the date of such notice were the date of the redemption), setting forth the details of such computation. Two Business Days prior to such redemption, the Company shall deliver to each holder of bonds of the 2028 Series a certificate of a Senior Financial Officer specifying the calculation of such Make-Whole Amount as of the specified redemption date. Except as set forth above, the bonds of the 2028 Series are not redeemable prior to March 15, 2028.

The principal hereof and the interest accrued hereon may be declared or may become due on the conditions, in the manner, and at the time set forth in the Mortgage, upon the occurrence of a completed default as in the Mortgage provided.

At the option of the registered owner, any bonds of the 2028 Series, upon surrender thereof at the office or agency of the Company in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri, together with a written instrument of transfer in form approved by the Company duly executed by the registered owner or his duly authorized attorney, shall, subject to the provisions of Section 2.05 of the Original Indenture, be exchangeable for a like aggregate amount of fully registered bonds of the same series of other authorized denominations.

This bond is transferable as prescribed in the Mortgage by the registered owner hereof in person, or by his duly authorized attorney, at the office or agency of the Company in the Borough of Manhattan, The City of New York, or in the City of St. Louis, upon surrender and cancellation of this bond and upon presentation of a written instrument of transfer, duly executed, with signature guaranteed by a signature guarantor that is a participant in a nationally recognized signature guaranty program, and upon payment, if the Company shall require it, of the transfer charges prescribed in the Mortgage, and thereupon, a new fully registered bond of the same series for a like principal amount will be issued to the transferee in exchange herefor as provided in the Mortgage. The Company and the Trustee may deem and treat the person in whose name this bond is registered as the absolute owner hereof for the purpose of receiving payment and for all other purposes.

No recourse shall be had for the payment of the principal of or of interest on this bond against any incorporator or any past, present or future subscriber to the capital stock, stockholder,

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officer or director of the Company or of any predecessor or successor corporation, as such, either directly or through the Company or any predecessor or successor corporation, under any rule of law, statute or constitution or by the enforcement of any assessment or otherwise, all such liability of incorporators, subscribers, stockholders, officers and directors, as such, being released by the owner hereof by the acceptance of this bond and being likewise waived and released by the terms of the Mortgage.

Each holder of this bond will be deemed, by its acceptance hereof, to have (i) agreed to the confidentiality provisions set forth in Section 16 of the Bond Purchase Agreement dated as of August 3, 2012, between the Company and the purchasers of bonds of the 2028 Series listed in Schedule A thereto (the “Bond Purchase Agreement”) and (ii) made the representations set forth in Section 6.1 of the Bond Purchase Agreement.

This bond shall not become obligatory until UMB Bank & Trust, n.a., the Trustee under the Mortgage, or its successor thereunder, shall have signed the form of certificate endorsed hereon.

IN WITNESS WHEREOF, LACLEDE GAS COMPANY has caused this instrument to be signed in its name by its President or one of its Vice-Presidents, by his or her signature or a facsimile thereof, and a facsimile of its corporate seal to be imprinted hereon and attested by its Secretary or one of its Assistant Secretaries, by his or her signature or a facsimile thereof.

Dated	LACLEDE GAS COMPANY
	By
		President
ATTEST:
Secretary

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(FORM OF TRUSTEE'S CERTIFICATE)

This bond is one of the bonds, of the Series herein designated, provided for in the within-mentioned Mortgage.

UMB BANK & TRUST, N.A.
Trustee
By
	Authorized Signatory

and

WHEREAS, all conditions and requirements necessary to make this Thirty-First Supplemental Indenture a valid, binding and legal instrument have been done, performed and fulfilled, and the execution and delivery hereof have been in all respects duly authorized;

NOW, THEREFORE, THIS THIRTY-FIRST SUPPLEMENTAL INDENTURE WITNESSETH: That Laclede Gas Company, in consideration of the premises and of one dollar to it duly paid by the Trustee at or before the ensealing and delivery of these presents, the receipt whereof is hereby acknowledged, and in order to secure the payment both of the principal of and interest and premium, if any, on the bonds from time to time issued under the Mortgage, according to their tenor and effect and the performance of all the provisions of the Mortgage and of said bonds, hath granted, bargained and sold, released, conveyed, assigned, transferred, mortgaged, pledged, set over and confirmed, and by these presents doth grant, bargain and sell, release, convey, assign, transfer, mortgage, pledge, set over and confirm unto UMB Bank & Trust, n.a., as Trustee, and to its successor or successors in said trust and its and their assigns forever, all the following described properties of the Company, that is to say:

All several parcels of real estate more particularly described in the Original Indenture as Parcels Nos. 1 to 14 inclusive, and in the First Supplemental Indenture as Parcels (a) to (i) inclusive, and the Third Supplemental Indenture as Parcels II to VI inclusive, and in the Fourth Supplemental Indenture in paragraphs II to VII inclusive, beginning on page 13 and extending to page 15 thereof, and in the Fifth Supplemental Indenture in paragraphs II to X inclusive, beginning on page 14 and extending to page 17 thereof, and in the Sixth Supplemental Indenture in paragraphs II to XI inclusive, beginning on page 14 and extending to page 21 thereof, and in the Seventh Supplemental Indenture in paragraphs II to XIII inclusive, beginning on page 16 and extending to page 24 thereof, and in the Eighth Supplemental Indenture in paragraphs II to VIII inclusive, beginning on page 16 and extending to page 19 thereof, and in the Ninth Supplemental Indenture in paragraphs II and III, beginning on page 11 and extending to page 12 thereof, and in the Tenth Supplemental Indenture in paragraphs II to VI inclusive, beginning on page 11 and extending to page 13 thereof, and in the Eleventh Supplemental Indenture in paragraphs II and III, beginning on page 13 and extending to page 16 thereof, and in the Twelfth Supplemental Indenture on page 15 thereof, and in the Thirteenth Supplemental Indenture beginning on page 16 and extending to page 24 thereof, and in the Fifteenth Supplemental Indenture beginning on page 15 and extending to page 39 thereof, and in the Sixteenth Supplemental Indenture beginning on page 16 and extending to page 17 thereof, and in the Seventeenth Supplemental

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Indenture beginning on page 17 and extending to page 19 thereof, and in the Eighteenth Supplemental Indenture beginning on page 15 and extending to page 16 thereof, and in the Nineteenth Supplemental Indenture beginning on page 16 and extending to page 17 thereof, and in the Twentieth Supplemental Indenture beginning on page 17 and extending to page 19 thereof, and in the Twenty-First Supplemental Indenture beginning on page 17 and extending to page 19 thereof, and in the Twenty-Second Supplemental Indenture beginning on page 10 and extending to page 11 thereof, and in the Twenty-Third Supplemental Indenture beginning on page 10 and extending to page 11 thereof, and in the Twenty-Fourth Supplemental Indenture beginning on page 10 and extending to page 11 thereof, and in the Twenty-Fifth Supplemental Indenture beginning on page 13 and extending to page 14 thereof, and in the Twenty-Sixth Supplemental Indenture beginning on page 13 and extending to page 15 thereof; and in the Twenty-Seventh Supplemental Indenture beginning on page 14 and extending to page 15 thereof; and in the Twenty-Eighth Supplemental Indenture beginning on page 14 and extending to page 15 thereof; and in the Twenty-Ninth Supplemental Indenture beginning on page 14 and extending to page 15 thereof; and in the Thirtieth Supplemental Indenture beginning on page 14 and extending to page 16 thereof; except any parcel or part of such real estate heretofore released from the lien of the Mortgage, or to which the Company and the Trustee have heretofore disclaimed any right, title, or interest.

TOGETHER WITH all other property, whether real, personal or mixed (except any hereinafter expressly excepted), and whether now owned or hereafter acquired by the Company and wheresoever situated, including (without in anywise limiting or impairing by the enumeration of the same the scope and intent of the foregoing or of any general description contained in this Thirty First Supplemental Indenture) all real estate, lands, leases, leaseholds (except the last day of the term of any lease or leasehold), easements, licenses, permits, franchises, privileges, rights of way and other rights in or relating to real estate or the occupancy of lands, all rights of way and roads, all gas plants, gas containers, buildings and other structures and all offices, buildings and the contents thereof; all machinery, engines, boilers, gas machines, purifiers, scrubbers, retorts, tanks, pumps, regulators, meters, gas and mechanical appliances, conduits, gas or other pipes, gas mains and pipes, service pipes, fittings, valves and connections, tools, implements, apparatus, supplies, furniture and chattels; all federal, state, municipal and other franchises, privileges and permits; all lines for the distribution of gas for any purpose including pipes, conduits and all apparatus for use in connection therewith; and (except as hereinafter expressly excepted) all the right, title and interest of the Company in and to all other property of any kind or nature appertaining to and/or used and/or occupied and/or enjoyed in connection with any property hereinabove described or referred to;

AND TOGETHER WITH all and singular the tenements, hereditaments and appurtenances belonging or in anywise appertaining to the aforesaid property or any part thereof, with the reversion and reversions, remainder and remainders, and (subject to the provisions of Section 13.01 of the Original Indenture) the tolls, rents, revenues, issues, earnings, income, product and profits thereof, and all the estate, right, title and interest and claim whatsoever, at law as well as in equity, which the Company now has or may hereafter acquire in and to the aforesaid property and franchises and every part and parcel thereof;

Provided that all property of the kinds which by the terms of the Original Indenture are expressly excepted from the lien and operation thereof is expressly excepted herefrom with the

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same effect and to the same extent as in the Original Indenture provided with respect to such property so expressly excepted;

TO HAVE AND TO HOLD all such properties, real, personal, and mixed, granted, bargained, sold, released, conveyed, assigned, transferred, mortgaged, pledged, set over or confirmed by the Company as aforesaid, or intended so to be, unto the Trustee and its successors and assigns forever;

Subject, however, as to all property embraced herein to all of the restrictions, exceptions and reservations of easements, rights of way or otherwise, contained in any and all deeds and/or other conveyances under or through which the Company acquired or shall acquire and/or claims or shall claim title thereto, and to the restrictions, exceptions, reservations and provisions in the Mortgage specifically set forth; and

Subject further, with respect to the premises, property, franchises and rights owned by the Company at the date of execution hereof, to excepted encumbrances as defined in Section 1.06 of the Original Indenture, and subject, with respect to property acquired after the date of execution of the Original Indenture or hereafter acquired, to all excepted encumbrances, all other defects and limitations of title and to all other encumbrances existing at the time of such acquisition, including any purchase money mortgage or lien upon such property created by the Company at the time of the acquisition of such property.

IN TRUST NEVERTHELESS, upon the terms and trusts in the Original Indenture and this Thirty-First Supplemental Indenture set forth, for the benefit and security of those who shall hold the bonds and coupons issued and to be issued under the Mortgage, or any of them, in accordance with the terms of the Mortgage without preference, priority or distinction as to lien of any of said bonds and coupons over any other thereof by reason of priority in the time of the issue or negotiation thereof or for any other reason whatsoever, subject, however, to the provisions in reference to extended, transferred or pledged coupons and claims for interest in the Original Indenture set forth; it being intended that the lien and security of all of said bonds and coupons of all series issued or to be issued hereunder shall take effect from the execution and delivery of the Mortgage, and that the lien and security of the Mortgage shall take effect from the date of execution and delivery of the Original Indenture as though all of the said bonds of all series were actually authenticated and delivered and issued upon such date.

And the Company, for itself and its successors and assigns, does hereby covenant and agree to and with the Trustee and its successor or successors in such trust, for the benefit of those who shall hold the bonds of the 2023 Series, the bonds of the 2028 Series, or any of such bonds, as follows:

ARTICLE IDEFINITIONS

SECTION 1.1Terms Defined by Reference. For all purposes of this Thirty-First Supplemental Indenture, except as herein otherwise expressly provided or unless the context otherwise requires, the terms defined in Sections 1.2 to 1.37 hereof shall have the meanings

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specified in such Sections, and all other terms which are defined in the Original Indenture (including those defined by reference to the Trust Indenture Act of 1939, as amended, or the Securities Act of 1933, as amended) shall have the meanings assigned to them in the Original Indenture.

SECTION 1.2Business Day. The term “Business Day” shall mean a day other than a (i) Saturday, (ii) Sunday, or (iii) day on which commercial banks are authorized or required by law, regulation or executive order to close in the City of New York, New York. If a payment date is not a Business Day at a place of payment, payment may be made at that place on the next succeeding day that is a Business Day, and no interest shall accrue for the intervening period.

SECTION 1.3Trustee. The term “the Trustee” shall mean the party of the second part hereto, UMB Bank & Trust, n.a., and, subject to the provisions of Article XVIII of the Original Indenture, shall also include its successors and assigns.

SECTION 1.4Original Indenture. The term “Original Indenture” shall mean the indenture of mortgage and deed of trust dated as of February 1, 1945, hereinbefore referred to.

SECTION 1.5First Supplemental Indenture. The term “First Supplemental Indenture” shall mean the supplemental indenture dated as of December 1, 1946, hereinbefore referred to.

SECTION 1.6Second Supplemental Indenture. The term “Second Supplemental Indenture” shall mean the supplemental indenture dated as of March 15, 1948, hereinbefore referred to.

SECTION 1.7Third Supplemental Indenture. The term “Third Supplemental Indenture” shall mean the supplemental indenture dated as of April 1, 1951, hereinbefore referred to.

SECTION 1.8Fourth Supplemental Indenture. The term “Fourth Supplemental Indenture” shall mean the supplemental indenture dated as of December 1, 1954, hereinbefore referred to.

SECTION 1.9Fifth Supplemental Indenture. The term “Fifth Supplemental Indenture” shall mean the supplemental indenture dated as of May 1, 1957, hereinbefore referred to.

SECTION 1.10Sixth Supplemental Indenture. The term “Sixth Supplemental Indenture” shall mean the supplemental indenture dated as of July 1, 1960, hereinbefore referred to.

SECTION 1.11Seventh Supplemental Indenture. The term “Seventh Supplemental Indenture” shall mean the supplemental indenture dated as of June 1, 1964, hereinbefore referred to.

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SECTION 1.12Eighth Supplemental Indenture. The term “Eighth Supplemental Indenture” shall mean the supplemental indenture dated as of April 15, 1966, hereinbefore referred to.

SECTION 1.13Ninth Supplemental Indenture. The term “Ninth Supplemental Indenture” shall mean the supplemental indenture dated as of May 1, 1968, hereinbefore referred to.

SECTION 1.14Tenth Supplemental Indenture. The term “Tenth Supplemental Indenture” shall mean the supplemental indenture dated as of May 15, 1970, hereinbefore referred to.

SECTION 1.15Eleventh Supplemental Indenture. The term “Eleventh Supplemental Indenture” shall mean the supplemental indenture dated as of March 15, 1972, hereinbefore referred to.

SECTION 1.16Twelfth Supplemental Indenture. The term “Twelfth Supplemental Indenture” shall mean the supplemental indenture dated as of March 15, 1974, hereinbefore referred to.

SECTION 1.17Thirteenth Supplemental Indenture. The term “Thirteenth Supplemental Indenture” shall mean the supplemental indenture dated as of June 1, 1975, hereinbefore referred to.

SECTION 1.18Fourteenth Supplemental Indenture. The term “Fourteenth Supplemental Indenture” shall mean the supplemental indenture dated as of October 26, 1976, hereinbefore referred to.

SECTION 1.19Fifteenth Supplemental Indenture. The term “Fifteenth Supplemental Indenture” shall mean the supplemental indenture dated as of July 15, 1979, hereinbefore referred to.

SECTION 1.20Sixteenth Supplemental Indenture. The term “Sixteenth Supplemental Indenture” shall mean the supplemental indenture dated as of May 1, 1986, hereinbefore referred to.

SECTION 1.21Seventeenth Supplemental Indenture. The term “Seventeenth Supplemental Indenture” shall mean the supplemental indenture dated as of May 15, 1988, hereinbefore referred to.

SECTION 1.22Eighteenth Supplemental Indenture. The term “Eighteenth Supplemental Indenture” shall mean the supplemental indenture dated as of November 15, 1989, hereinbefore referred to.

SECTION 1.23Nineteenth Supplemental Indenture. The term “Nineteenth Supplemental Indenture” shall mean the supplemental indenture dated as of May 15, 1991, hereinbefore referred to.

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SECTION 1.24Twentieth Supplemental Indenture. The term “Twentieth Supplemental Indenture” shall mean the supplemental indenture dated as of November 1, 1992, hereinbefore referred to.

SECTION 1.25Twenty-First Supplemental Indenture. The term “Twenty-First Supplemental Indenture” shall mean the supplemental indenture dated as of May 1, 1993, hereinbefore referred to.

SECTION 1.26Twenty-Second Supplemental Indenture. The term “Twenty-Second Supplemental Indenture” shall mean the supplemental indenture dated as of November 15, 1995, hereinbefore referred to.

SECTION 1.27Twenty-Third Supplemental Indenture. The term “Twenty-Third Supplemental Indenture” shall mean the supplemental indenture dated as of October 15, 1997, hereinbefore referred to.

SECTION 1.28Twenty-Fourth Supplemental Indenture. The term “Twenty-Fourth Supplemental Indenture” shall mean the supplemental indenture dated as of June 1, 1999 hereinbefore referred to.

SECTION 1.29Twenty-Fifth Supplemental Indenture. The term “Twenty-Fifth Supplemental Indenture” shall mean the supplemental indenture dated as of September 15, 2000 hereinbefore referred to.

SECTION 1.30Twenty-Sixth Supplemental Indenture. The term “Twenty-Sixth Supplemental Indenture” shall mean the supplemental indenture dated as of June 15, 2001 hereinbefore referred to.

SECTION 1.31Twenty-Seventh Supplemental Indenture. The term “Twenty-Seventh Supplemental Indenture” shall mean the supplemental indenture dated as of April 15, 2004 hereinbefore referred to.

SECTION 1.32Twenty-Eighth Supplemental Indenture. The term “Twenty-Eighth Supplemental Indenture” shall mean the supplemental indenture dated as of April 15, 2004 hereinbefore referred to.

SECTION 1.33Twenty-Ninth Supplemental Indenture. The term “Twenty-Ninth Supplemental Indenture” shall mean the supplemental indenture dated as of June 1, 2006 hereinbefore referred to.

SECTION 1.34Thirtieth Supplemental Indenture. The term “Thirtieth Supplemental Indenture: shall mean the supplemental indenture dated as of September 15, 2008 hereinbefore referred to.

SECTION 1.35Mortgage. The term “Mortgage” shall mean the Original Indenture as supplemented by the First, Second, Third, Fourth, Fifth, Sixth, Seventh, Eighth, Ninth, Tenth, Eleventh, Twelfth, Thirteenth, Fourteenth, Fifteenth, Sixteenth, Seventeenth, Eighteenth, Nineteenth, Twentieth, Twenty-First, Twenty-Second, Twenty-Third, Twenty-Fourth, Twenty-

24

Fifth, Twenty-Sixth, Twenty-Seventh, Twenty-Eighth, Twenty-Ninth and Thirtieth Supplemental Indentures and hereby, or as the same may from time to time hereafter be supplemented, modified, altered or amended by any supplemental indenture entered into pursuant to the provisions of the Original Indenture.

SECTION 1.36Hereof, Hereunder, etc. The term “hereof,” “hereunder,” “hereto,” “hereby,” “hereinbefore,” and the like, refer to this Thirty-First Supplemental Indenture.

SECTION 1.372023 Series and 2028 Series. The terms “2023 Series” and “2028 Series” shall mean the series of First Mortgage Bonds created by this Thirty-First Supplemental Indenture, as in, respectively, Sections 2.1 and 4.1 hereof provided.

ARTICLE IICREATION, DESCRIPTION, REGISTRATION, TRANSFER ANDEXCHANGE OF THE 2023 SERIES OF BONDS

SECTION 2.1Creation and principal amount of the 2023 Series. The Company hereby creates a new series of bonds that may be authenticated and delivered, either before or after the filing or recording hereof, under any applicable provisions of the Original Indenture, and may be issued under the Mortgage, and each of which series shall be designated by the title “First Mortgage Bonds, 3.00% Series due March 15, 2023”. The aggregate principal amount of bonds of the 2023 Series that may be executed by the Company and authenticated is limited to Fifty-Five Million Dollars ($55,000,000), except bonds of such series authenticated and delivered pursuant to Section 2.4 or 2.6 hereof or Section 2.09 or Section 12.04 of the Original Indenture.

SECTION 2.2Date of Bonds. All bonds of the 2023 Series shall be dated as provided in Section 2.03 of the Original Indenture.

SECTION 2.3Denominations, etc. The bonds of the 2023 Series shall be issuable only as fully registered bonds without coupons, in the denomination of $250,000, and, at the option of the Company, in any multiple or multiples of $1,000, and such bonds, and the Trustee's certificate of authentication, shall, respectively, be substantially of the tenor and purport in this Thirty-First Supplemental Indenture above recited, and they may have such letters, numbers or other marks of identification, and such legends or endorsements, printed, lithographed or engraved thereon as the Company may deem appropriate and as are not inconsistent with the Mortgage, including any legend or legends permitted pursuant to Section 2.04 of the Original Indenture.

SECTION 2.4Exchange of Bonds. At the option of the registered owner, any bonds of the 2023 Series, upon surrender thereof at the office or agency of the Company in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri, together with a written instrument of transfer in form approved by the Company duly executed by the registered owner or his duly authorized attorney, shall, subject to the provisions of Section 2.05 of the Original Indenture, be exchangeable for a like aggregate amount of fully registered bonds of the same series of other authorized denominations.

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SECTION 2.5Registration of Bonds. The bonds of the 2023 Series are transferable as prescribed in the Mortgage by the registered owner thereof in person, or by his duly authorized attorney, at the office or agency of the Company in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri, upon surrender and cancellation of such bonds and upon presentation of a written instrument of transfer, duly executed, with signature guaranteed by a signature guarantor that is a participant in a nationally recognized signature guaranty program, and upon payment, if the Company shall require it, of the transfer charges prescribed in the Mortgage, and thereupon, new fully registered bonds of the same series for a like principal amount will be issued to the transferee in exchange therefor as provided in the Mortgage.

SECTION 2.6Temporary Bonds. Until bonds of the 2023 Series in definitive form are ready for delivery, there may be authenticated and delivered and issued, in lieu of any definitive bond or bonds of said series, temporary bonds of said series as provided in Section 2.08 of the Original Indenture. Such temporary bonds shall be substantially in the form of the definitive bonds of the 2023 Series, but with such omissions, insertions and variations as may be appropriate for temporary bonds, and may contain such reference to any provisions of the Mortgage as may be appropriate, all as determined by the Board of Directors.

SECTION 2.7Payment of Defaulted Interest. The person in whose name any bond of the 2023 Series is registered at the close of business on any record date (as hereinbelow defined) with respect to any interest payment date shall be entitled to receive the interest payable on such interest payment date notwithstanding the cancellation of such bond upon any transfer or exchange thereof subsequent to the record date and prior to such interest payment date, except if and to the extent the Company shall default in the payment of the interest due on such interest payment date, in which case such defaulted interest shall be paid to the person in whose name such bond is registered on the date of payment of such defaulted interest. The record date shall be March 1 or September 1, as the case may be, next preceding such interest payment date, or, if such March 1 or September 1 shall be a legal holiday or a day on which banking institutions in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri, are authorized by law to close, the next preceding day which shall not be a legal holiday or a day on which such institutions are so authorized to close.

SECTION 2.8Transfers or Exchanges of Bonds called for redemption. Anything in this Thirty-First Supplemental Indenture to the contrary notwithstanding, the Company shall not be required to make transfers or exchanges of bonds of the 2023 Series for a period of fifteen (15) days next preceding any selection of bonds of the 2023 Series to be redeemed, and the Company shall not be required to make transfers or exchanges of the principal amount of any of such bonds called or selected for redemption except in the case of any bond of the 2023 Series to be redeemed in part, the portion thereof not to be so redeemed.

SECTION 2.9Restrictive Legend. Bonds of the 2023 Series offered and sold to “accredited investors” (within the meaning of Rule 501(a)(1), (2), (3) or (7) of Regulation D under the Securities Act of 1933, as amended) shall be issued substantially in the form of such bonds set forth in the Recitals to this Thirty-First Supplemental Indenture, containing the first legend set forth thereon (for purposes of this Section 2.9, the “Restrictive Legend”) and the other

26

legends required thereby and numbered from 1 upward with the prefix “R”, duly executed by the Company and authenticated by the Trustee as herein provided.

The Company shall issue a bond of the 2023 Series that does not bear the Restrictive Legend in replacement of a bond of the applicable series bearing the Restrictive Legend at the request of any holder following such request if (i) the holder shall have obtained an opinion of counsel reasonably acceptable to the Company in form and substance reasonably satisfactory to the Company to the effect that such bond may lawfully be disposed of without registration, qualification or legend pursuant to Rule 144 under the Securities Act of 1933, as amended, or (ii) the holder sells such bond pursuant to Rule 144 under the Securities Act of 1933, as amended, or an effective registration statement.

ARTICLE IIIREDEMPTION OF BONDS OF THE 2023 SERIES

SECTION 3.1Circumstances in Which Redeemable. Bonds of the 2023 Series shall be redeemable, in whole or in part, at 100% of the principal amount thereof, together with accrued interest thereon to the date fixed for redemption at any time before maturity pursuant to the provisions of paragraph (B) of Section 13.06 of the Original Indenture.

SECTION 3.2Additional Circumstances in Which Redeemable. Bonds of the 2023 Series shall also be redeemable, at the option of the Company, in whole at any time or in part from time to time, at a redemption price equal to 100% of the principal amount to be redeemed plus the Make-Whole Amount (as defined below) determined for the redemption date with respect to such principal amount, plus accrued interest thereon to the date fixed for redemption without premium. Any redemption in part under this Section 3.2 shall be made pro rata to the holders of all bonds of the 2023 Series at the time outstanding upon the same terms and conditions.

For purposes of this Section 3.2:

“Make-Whole Amount” means, with respect to any bond of the 2023 Series, an amount equal to the excess, if any, of the Discounted Value of the Remaining Scheduled Payments with respect to the Called Principal of such bond over the amount of such Called Principal, provided that the Make-Whole Amount may in no event be less than zero. For the purposes of determining the Make-Whole Amount, the following terms have the following meanings:

“Business Day” shall have the meaning set forth in the form of bonds of the 2023 Series.

“Called Principal” means, with respect to any bond, the principal of such bond that is to be redeemed or has become or is declared to be immediately due and payable pursuant to the Mortgage, as the context requires.

“Discounted Value” means, with respect to the Called Principal of any bond, the amount obtained by discounting all Remaining Scheduled Payments with respect to such Called Principal from their respective scheduled due dates to the Settlement Date with

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respect to such Called Principal, in accordance with accepted financial practice and at a discount factor (applied on the same periodic basis as that on which interest on the bonds is payable) equal to the Reinvestment Yield with respect to such Called Principal.

“Reinvestment Yield” means, with respect to the Called Principal of any bond, .50% over the yield to maturity implied by (i) the yields reported as of 10:00 a.m. (New York City time) on the second Business Day preceding the Settlement Date with respect to such Called Principal, on the display designated as “Page PX1” (or such other display as may replace Page PX1) on Bloomberg Financial Markets for the most recently issued actively traded on the run U.S. Treasury securities having a maturity equal to the Remaining Average Life of such Called Principal as of such Settlement Date, or (ii) if such yields are not reported as of such time or the yields reported as of such time are not ascertainable (including by way of interpolation), the Treasury Constant Maturity Series Yields reported, for the latest day for which such yields have been so reported as of the second Business Day preceding the Settlement Date with respect to such Called Principal, in Federal Reserve Statistical Release H.15 (or any comparable successor publication) for U.S. Treasury securities having a constant maturity equal to the Remaining Average Life of such Called Principal as of such Settlement Date.

In the case of each determination under clause (i) or clause (ii), as the case may be, of the preceding paragraph, such implied yield will be determined, if necessary, by (a) converting U.S. Treasury bill quotations to bond equivalent yields in accordance with accepted financial practice and (b) interpolating linearly between (1) the applicable U.S. Treasury security with the maturity closest to and greater than such Remaining Average Life and (2) the applicable U.S. Treasury security with the maturity closest to and less than such Remaining Average Life. The Reinvestment Yield shall be rounded to the number of decimal places as appears in the interest rate of the applicable bond.

“Remaining Average Life” means, with respect to any Called Principal, the number of years (calculated to the nearest one-twelfth year) obtained by dividing (i) such Called Principal into (ii) the sum of the products obtained by multiplying (a) the principal component of each Remaining Scheduled Payment with respect to such Called Principal by (b) the number of years (calculated to the nearest one-twelfth year) that will elapse between the Settlement Date with respect to such Called Principal and the scheduled due date of such Remaining Scheduled Payment.

“Remaining Scheduled Payments” means, with respect to the Called Principal of any bond, all payments of such Called Principal and interest thereon that would be due after the Settlement Date with respect to such Called Principal if no payment of such Called Principal were made prior to its scheduled due date, provided that if such Settlement Date is not a date on which interest payments are due to be made under the terms of the Bonds, then the amount of the next succeeding scheduled interest payment will be reduced by the amount of interest accrued to such Settlement Date and required to be paid on such Settlement Date pursuant to this section.

“Settlement Date” means, with respect to the Called Principal of any bond, the date on which such Called Principal is to be redeemed pursuant to this section.

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SECTION 3.3Purchase of Bonds. The Company will not and will not permit any affiliate to purchase, redeem or otherwise acquire, directly or indirectly, any of the outstanding bonds of the 2023 Series except (a) upon the redemption of such bonds in accordance with the terms of Section 3.2 hereof and such bonds or (b) pursuant to an offer to purchase made by the Company or an affiliate pro rata to the holders of all bonds of the 2023 Series at the time outstanding upon the same terms and conditions. Any such offer shall provide each holder with sufficient information to enable it to make an informed decision with respect to such offer, and shall remain open for at least 10 Business Days. If the holders of more than 25% of the principal amount of the bonds of the 2023 Series then outstanding accept such offer, the Company shall promptly notify the remaining holders of such fact and the expiration date for the acceptance by holders of bonds of the 2023 Series of such offer shall be extended by the number of days necessary to give each such remaining holder at least 10 Business Days from its receipt of such notice to accept such offer. The Company will promptly cancel all bonds acquired by it or any affiliate pursuant to any payment, redemption or purchase of bonds pursuant to this Article III and no bonds may be issued in substitution or exchange for any such bonds.

SECTION 3.4Notice of Intention to Redeem. Article XII of the Original Indenture is and shall be applicable to any redemption of bonds of the 2023 Series. The notice of intention to redeem provided for in Section 12.02 of the Original Indenture need not be published with respect to bonds of the 2023 Series but shall be given by mailing a copy thereof to each registered owner thereof, directed to his registered address, not less than thirty (30) nor more than sixty (60) days prior to the date fixed for redemption.

SECTION 3.5No Other Redemptions. Except as set forth in Section 3.1 and Section 3.2 hereof, the bonds of the 2023 Series are not redeemable prior to March 15, 2023.

ARTICLE IVCREATION, DESCRIPTION, REGISTRATION, TRANSFER ANDEXCHANGE OF THE 2028 SERIES OF BONDS

SECTION 4.1Creation and Principal Amount of the 2028 Series. The Company hereby creates a new series of bonds that may be authenticated and delivered, either before or after the filing or recording hereof, under any applicable provisions of the Original Indenture, and may be issued under the Mortgage, and each of which series shall be designated by the title “First Mortgage Bonds, 3.40% Series due March 15, 2028”. The aggregate principal amount of bonds of the 2028 Series that may be executed by the Company and authenticated is limited to Forty-Five Million Dollars ($45,000,000), except bonds of such series authenticated and delivered pursuant to Section 2.4 or 2.6 hereof or Section 2.09 or Section 12.04 of the Original Indenture.

SECTION 4.2Date of Bonds. All bonds of the 2028 Series shall be dated as provided in Section 2.03 of the Original Indenture.

SECTION 4.3Denominations, etc. The bonds of the 2028 Series shall be issuable only as fully registered bonds without coupons, in the denomination of $250,000, and, at the option of the Company, in any multiple or multiples of $1,000, and such bonds, and the Trustee's

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certificate of authentication, shall, respectively, be substantially of the tenor and purport in this Thirty-First Supplemental Indenture above recited, and they may have such letters, numbers or other marks of identification, and such legends or endorsements, printed, lithographed or engraved thereon as the Company may deem appropriate and as are not inconsistent with the Mortgage, including any legend or legends permitted pursuant to Section 2

SECTION 4.4Exchange of Bonds. At the option of the registered owner, any bonds of the 2028 Series, upon surrender thereof at the office or agency of the Company in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri, together with a written instrument of transfer in form approved by the Company duly executed by the registered owner or his duly authorized attorney, shall, subject to the provisions of Section 2.05 of the Original Indenture, be exchangeable for a like aggregate amount of fully registered bonds of the same series of other authorized denominations.

SECTION 4.5Registration of Bonds. The bonds of the 2028 Series are transferable as prescribed in the Mortgage by the registered owner thereof in person, or by his duly authorized attorney, at the office or agency of the Company in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri, upon surrender and cancellation of such bonds and upon presentation of a written instrument of transfer, duly executed, with signature guaranteed by a signature guarantor that is a participant in a nationally recognized signature guaranty program, and upon payment, if the Company shall require it, of the transfer charges prescribed in the Mortgage, and thereupon, new fully registered bonds of the same series for a like principal amount will be issued to the transferee in exchange therefor as provided in the Mortgage.

SECTION 4.6Temporary Bonds. Until bonds of the 2028 Series in definitive form are ready for delivery, there may be authenticated and delivered and issued, in lieu of any definitive bond or bonds of said series, temporary bonds of said series as provided in Section 2.08 of the Original Indenture. Such temporary bonds shall be substantially in the form of the definitive bonds of the 2028 Series, but with such omissions, insertions and variations as may be appropriate for temporary bonds, and may contain such reference to any provisions of the Mortgage as may be appropriate, all as determined by the Board of Directors.

SECTION 4.7Payment of Defaulted Interest. The person in whose name any bond of the 2028 Series is registered at the close of business on any record date (as hereinbelow defined) with respect to any interest payment date shall be entitled to receive the interest payable on such interest payment date notwithstanding the cancellation of such bond upon any transfer or exchange thereof subsequent to the record date and prior to such interest payment date, except if and to the extent the Company shall default in the payment of the interest due on such interest payment date, in which case such defaulted interest shall be paid to the person in whose name such bond is registered on the date of payment of such defaulted interest. The record date shall be March 1 or September 1, as the case may be, next preceding such interest payment date, or, if such March 1 or September 1 shall be a legal holiday or a day on which banking institutions in the Borough of Manhattan, The City of New York, or in the City of St. Louis, State of Missouri, are authorized by law to close, the next preceding day which shall not be a legal holiday or a day on which such institutions are so authorized to close.

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SECTION 4.8Transfers or Exchanges of Bonds Called for Redemption. Anything in this Thirty-First Supplemental Indenture to the contrary notwithstanding, the Company shall not be required to make transfers or exchanges of bonds of the 2028 Series for a period of fifteen (15) days next preceding any selection of bonds of the 2028 Series to be redeemed, and the Company shall not be required to make transfers or exchanges of the principal amount of any of such bonds called or selected for redemption except in the case of any bond of the 2028 Series to be redeemed in part, the portion thereof not to be so redeemed.

SECTION 4.9Restrictive Legend. Bonds of the 2028 Series offered and sold to “accredited investors” (within the meaning of Rule 501(a)(1), (2), (3) or (7) of Regulation D under the Securities Act of 1933, as amended) shall be issued substantially in the form of such bonds set forth in the Recitals to this Thirty-First Supplemental Indenture, containing the first legend set forth thereon (for purposes of this Section 4.9, the “Restrictive Legend”) and the other legends required thereby and numbered from 1 upward with the prefix “R”, duly executed by the Company and authenticated by the Trustee as herein provided.

The Company shall issue a bond of the 2028 Series that does not bear the Restrictive Legend in replacement of a bond of the applicable series bearing the Restrictive Legend at the request of any holder following such request if (i) the holder shall have obtained an opinion of counsel reasonably acceptable to the Company in form and substance reasonably satisfactory to the Company to the effect that such bond may lawfully be disposed of without registration, qualification or legend pursuant to Rule 144 under the Securities Act of 1933, as amended, or (ii) the holder sells such bond pursuant to Rule 144 under the Securities Act of 1933, as amended, or an effective registration statement.

ARTICLE VREDEMPTION OF BONDS OF THE 2028 SERIES

SECTION 5.1Circumstances in Which Redeemable. Bonds of the 2028 Series shall be redeemable, in whole or in part, at 100% of the principal amount thereof, together with accrued interest thereon to the date fixed for redemption at any time before maturity pursuant to the provisions of paragraph (B) of Section 13.06 of the Original Indenture.

SECTION 5.2Additional Circumstances in Which Redeemable. Bonds of the 2028 Series shall also be redeemable, at the option of the Company, in whole at any time or in part from time to time, at a redemption price equal to 100% of the principal amount to be redeemed plus the Make-Whole Amount (as defined below) determined for the redemption date with respect to such principal amount, plus accrued interest thereon to the date fixed for redemption without premium. Any redemption in part under this Section 5.2 shall be made pro rata to the holders of all bonds of the 2028 Series at the time outstanding upon the same terms and conditions.

For purposes of this Section 5.2:

“Make-Whole Amount” means, with respect to any bond of the 2028 Series, an amount equal to the excess, if any, of the Discounted Value of the Remaining Scheduled Payments with

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respect to the Called Principal of such bond over the amount of such Called Principal, provided that the Make-Whole Amount may in no event be less than zero. For the purposes of determining the Make-Whole Amount, the following terms have the following meanings:

“Business Day” shall have the meaning set forth in the form of bonds of the 2028 Series.

“Called Principal” means, with respect to any bond, the principal of such bond that is to be redeemed or has become or is declared to be immediately due and payable pursuant to the Mortgage, as the context requires.

“Discounted Value” means, with respect to the Called Principal of any bond, the amount obtained by discounting all Remaining Scheduled Payments with respect to such Called Principal from their respective scheduled due dates to the Settlement Date with respect to such Called Principal, in accordance with accepted financial practice and at a discount factor (applied on the same periodic basis as that on which interest on the bonds is payable) equal to the Reinvestment Yield with respect to such Called Principal.

“Reinvestment Yield” means, with respect to the Called Principal of any bond, .50% over the yield to maturity implied by (i) the yields reported as of 10:00 a.m. (New York City time) on the second Business Day preceding the Settlement Date with respect to such Called Principal, on the display designated as “Page PX1” (or such other display as may replace Page PX1) on Bloomberg Financial Markets for the most recently issued actively traded on the run U.S. Treasury securities having a maturity equal to the Remaining Average Life of such Called Principal as of such Settlement Date, or (ii) if such yields are not reported as of such time or the yields reported as of such time are not ascertainable (including by way of interpolation), the Treasury Constant Maturity Series Yields reported, for the latest day for which such yields have been so reported as of the second Business Day preceding the Settlement Date with respect to such Called Principal, in Federal Reserve Statistical Release H.15 (or any comparable successor publication) for U.S. Treasury securities having a constant maturity equal to the Remaining Average Life of such Called Principal as of such Settlement Date.

In the case of each determination under clause (i) or clause (ii), as the case may be, of the preceding paragraph, such implied yield will be determined, if necessary, by (a) converting U.S. Treasury bill quotations to bond equivalent yields in accordance with accepted financial practice and (b) interpolating linearly between (1) the applicable U.S. Treasury security with the maturity closest to and greater than such Remaining Average Life and (2) the applicable U.S. Treasury security with the maturity closest to and less than such Remaining Average Life. The Reinvestment Yield shall be rounded to the number of decimal places as appears in the interest rate of the applicable bond.

“Remaining Average Life” means, with respect to any Called Principal, the number of years (calculated to the nearest one-twelfth year) obtained by dividing (i) such Called Principal into (ii) the sum of the products obtained by multiplying (a) the principal component of each Remaining Scheduled Payment with respect to such Called Principal by (b) the number of years (calculated to the nearest one-twelfth year) that will elapse

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between the Settlement Date with respect to such Called Principal and the scheduled due date of such Remaining Scheduled Payment.

“Remaining Scheduled Payments” means, with respect to the Called Principal of any bond, all payments of such Called Principal and interest thereon that would be due after the Settlement Date with respect to such Called Principal if no payment of such Called Principal were made prior to its scheduled due date, provided that if such Settlement Date is not a date on which interest payments are due to be made under the terms of the Bonds, then the amount of the next succeeding scheduled interest payment will be reduced by the amount of interest accrued to such Settlement Date and required to be paid on such Settlement Date pursuant to this section.

“Settlement Date” means, with respect to the Called Principal of any bond, the date on which such Called Principal is to be redeemed pursuant to this section.

SECTION 5.3Purchase of Bonds. The Company will not and will not permit any affiliate to purchase, redeem or otherwise acquire, directly or indirectly, any of the outstanding bonds of the 2028 Series except (a) upon the redemption of such bonds in accordance with the terms of Section 5.2 hereof and such bonds or (b) pursuant to an offer to purchase made by the Company or an affiliate pro rata to the holders of all bonds of the 2028 Series at the time outstanding upon the same terms and conditions. Any such offer shall provide each holder with sufficient information to enable it to make an informed decision with respect to such offer, and shall remain open for at least 10 Business Days. If the holders of more than 25% of the principal amount of the bonds of the 2028 Series then outstanding accept such offer, the Company shall promptly notify the remaining holders of such fact and the expiration date for the acceptance by holders of bonds of the 2028 Series of such offer shall be extended by the number of days necessary to give each such remaining holder at least 10 Business Days from its receipt of such notice to accept such offer. The Company will promptly cancel all bonds acquired by it or any affiliate pursuant to any payment, redemption or purchase of bonds pursuant to this Article V and no bonds may be issued in substitution or exchange for any such bonds.

SECTION 5.4Notice of Intention to Redeem. Article XII of the Original Indenture is and shall be applicable to any redemption of bonds of the 2028 Series. The notice of intention to redeem provided for in Section 12.02 of the Original Indenture need not be published with respect to bonds of the 2028 Series but shall be given by mailing a copy thereof to each registered owner thereof, directed to his registered address, not less than thirty nor more than sixty (60) days prior to the date fixed for redemption.

SECTION 5.5No Other Redemptions. Except as set forth in Section 5.1 and Section 5.2 hereof, the bonds of the 2028 Series are not redeemable prior to March 15, 2028.

ARTICLE VIPARTICULAR COVENANTS OF THE COMPANY

SECTION 6.1Restrictions as to Dividends. So long as any of the bonds of the 2023 Series or any bonds of the 2028 Series are outstanding, the Company will not (a) declare any

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dividends (other than dividends in common stock) on any common stock, or order the making of any distribution on any shares of common stock or to owners of common stock or (b) purchase, redeem or otherwise acquire or retire for value any shares of common stock, if the aggregate net amount of such declarations, distributions so ordered, purchases, redemptions, acquisitions and retirements after September 30, 1953, would exceed the sum of (y) the Net Income Available for Common Stock for the period beginning October 1, 1953, and ending with the last day of the calendar quarter immediately preceding the calendar quarter in which such dividend is declared, distribution ordered, or purchase, redemption, acquisition or retirement made, plus (z) Eight Million Dollars ($8,000,000).

The aggregate net amount of the declarations, distributions ordered, purchases, redemptions, acquisitions and retirements referred to in the first paragraph of this Section 6.1 shall be determined by deducting from the aggregate amount thereof the total amount of cash payments received by the Company after September 30, 1953, for any shares of common stock sold by the Company after September 30, 1953.

Net Income Available for Common Stock, for the purpose of this Section 6.1, for any period, means (1) the net income of the Company for such period computed according to the applicable system of accounts prescribed by the Public Service Commission of Missouri and any applicable orders of said Commission and (to the extent not prescribed by such system of accounts or orders) according to generally accepted accounting principles, less (2) an amount equal to the dividends accrued (whether or not declared or paid) during such period on any and all classes of stock having preference over the common stock as to assets or dividends.

For the purposes of the last preceding paragraph of this Section 6.1, the term “Public Service Commission of Missouri” shall also apply, and be deemed to refer, to any regulatory body which may (A) succeed said Commission with respect to jurisdiction over the accounting of the Company, or (B) supersede said Commission with respect to such jurisdiction, or (C) have such jurisdiction over phases of the Company's business or parts of its property over which said Commission shall not have jurisdiction.

SECTION 6.2Earnings Requirements for Additional Bonds. So long as any bonds of the 2023 Series or any bonds of the 2028 Series are outstanding, the Company shall not be entitled to have authenticated and delivered any bonds pursuant to Article VI, Article VII or Article VIII of the Original Indenture, except bonds which may be authenticated and delivered under Article VII of the Original Indenture, without the receipt by the Trustee of a net earnings certificate showing the net earnings to be as required by Section 6.05 of the Original Indenture, unless (in addition to all other requirements for the authentication and delivery of such bonds):

(a)net earnings of the Company after provision for depreciation, depletion and amortization of property, for any 12 consecutive calendar months within the 15 calendar months immediately preceding the date on which such additional bonds are to be issued, shall have been not less than 2 1/4 times the amount of the total annual interest charges upon the funded debt of the Company to be outstanding immediately after the issue of such additional bonds; and

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(b)the Trustee shall have received a certificate made, signed and verified by the same persons (including an independent public accountant where required) as would be required if such certificate were a net earnings certificate under the Original Indenture, showing the net earnings of the Company to be as required by the foregoing clause (a) of this Section 6.2. Such certificate shall show the net earnings and total annual interest charges referred to in said clause (a).

For the purposes of this Section 6.2, “funded debt” shall mean all indebtedness created or assumed by the Company maturing one year or more after the date of the creation or assumption thereof.

For the purposes of this Section 6.2, net earnings of the Company after provision for depreciation, depletion and amortization of property shall mean the total operating revenue and other income (net) of the Company less operating expenses (including provision for depreciation, depletion and amortization of property) and less taxes (excluding income and excess profits taxes or other taxes which are imposed on or measured by income). In the determination of net earnings of the Company the following additional requirements shall be applicable:

(i)No profits or losses from the sale or abandonment of capital assets or change in value of securities or other investments shall be taken into account in making such computations;

(ii)In case the Company shall have sold any property for a consideration in excess of $5,000,000, within or after the particular period for which the calculation is made, then, in computing the net earnings of the Company so available, the net earnings or net losses of such property for the whole of such period shall be excluded to the extent practicable on the basis of actual earnings and expenses of such property or on the basis of such estimates of the earnings and expenses of such property as the signers of a Treasurer's certificate filed with the Trustee shall deem proper;

(iii)In case the Company shall, within or after the particular period for which the calculation is made, have acquired (by purchase, merger, consolidation or otherwise) any property which within six months prior to the date of acquisition thereof by the Company has been used or operated by a person or persons other than the Company in a business similar to that in which it has been or is to be used or operated by the Company, then in computing the net earnings of the Company so available for such purposes there shall be included, to the extent that they may not have been otherwise included, the net earnings or net losses of the property so acquired for the whole of such period to the extent practicable on the basis of actual earnings and expenses of such property or on the basis of such estimates of the earnings and expenses of such property as the signers of a Treasurer's certificate filed with the Trustee shall deem proper. The net earnings or net losses of such property for the period preceding such acquisition shall in such case be ascertained and computed as provided in this clause (iii) as if such acquired property had been owned by the Company during the whole of such period; and

(iv)The “net earnings of property” referred to in clauses (ii) and (iii) of this Section 6.2 shall mean the net earnings of such property computed in the manner

35

provided in this definition for the computation of net earnings of the Company available for the pertinent purposes.

All accounting determinations required by this Section 6.2 shall (except to the extent, if any, to which the preceding provisions of this Section 6.2 may conflict with this provision) be made according to the applicable system of accounts prescribed by the Public Service Commission of Missouri and any applicable orders of said Commission and (to the extent not prescribed by such system of accounts or orders) according to generally accepted accounting principles.

For the purposes of this Section 6.2, the term “Public Service Commission of Missouri” shall be applicable as provided in Section 6.1 of this Article VI.

SECTION 6.3Postponement of Interest. So long as any bonds of the 2023 Series are outstanding, in order that any interest payment on the bonds of any of the 2023 Series may be postponed pursuant to clause (2) of Section 20.07 of the Original Indenture, there shall be required, in addition to all other prerequisites to such postponement provided in the Original Indenture, the consent of the owners of not less than seventy-five percent (75%) in principal amount of bonds of the 2023 Series at the time outstanding, such consent to be given at the same time as and in the same manner as the consent of the owners of other bonds required by said clause (2) of Section 20.07 of the Original Indenture. So long as any bonds of the 2028 Series are outstanding, in order that any interest payment on the bonds of any of the 2028 Series may be postponed pursuant to clause (2) of Section 20.07 of the Original Indenture, there shall be required, in addition to all other prerequisites to such postponement provided in the Original Indenture, the consent of the owners of not less than seventy-five percent (75%) in principal amount of bonds of the 2028 Series at the time outstanding, such consent to be given at the same time as and in the same manner as the consent of the owners of other bonds required by said clause (2) of Section 20.07 of the Original Indenture.

SECTION 6.4Information as to Company. So long as any bonds of the 2023 Series or bonds of the 2028 Series are outstanding, the Company shall comply with the information delivery requirements of Section 7.1 of the Bond Purchase Agreement (as defined in the forms of such bonds set forth in the Recitals to this Thirty-First Supplemental Indenture).

ARTICLE VIICOMPANY’S RESERVATION OF RIGHTS

SECTION 7.1Company’s Reservation of Rights. The Company reserves the right, without any consent, vote or other action by holders of bonds of the 2023 Series or of the bonds of the 2028 Series, or of any other subsequent series, to amend the Mortgage, as heretofore amended and supplemented, as follows:

To amend Section 21.04 of the Mortgage to read substantially as follows:

SECTION 21.04.    Any power, privilege or right expressly or impliedly reserved to or in any way conferred upon the Company by any provision of this Indenture, whether such power, privilege or right is in any way restricted or is

36

unrestricted, may be in whole or in part waived or surrendered or subjected to any restriction if at the time unrestricted or to additional restriction if already restricted. Anything in this Indenture to the contrary notwithstanding, the Company and the Trustee, at any time and from time to time, may enter into one or more indentures supplemental hereto, in form satisfactory to the Trustee, for any of the following purposes: (i) to enter into any further covenants, limitations or restrictions for the benefit of any one or more series of bonds issued hereunder and provide that a breach thereof shall be equivalent to a default under this Indenture; (ii) to cure any ambiguity or correct or supplement any defective or inconsistent provisions contained herein or in any supplemental indenture; (iii) to correct or amplify the description of any property at any time subject to the lien of the this Indenture, or better assure, convey and confirm unto the Trustee any property subject or required to be subjected to the lien of this Indenture, or subject to the lien of this Indenture additional property; or (iv) to change or eliminate any provision of this Indenture or to add any new provision to this Indenture provided that no such change, elimination or addition shall adversely affect the interests of the holders of bonds of any series. The Trustee is hereby authorized to join with the Company in the execution of any such instrument or instruments. Such instrument, executed and acknowledged as aforesaid, shall be delivered to the Trustee and thereupon if such instrument shall have been signed by the Trustee any modification of the provisions of these presents therein set forth, authorized by this Section, shall be binding upon the parties hereto, their successors and assigns, and the holders of the bonds and coupons hereby secured. Anything to the contrary notwithstanding, this Section shall not be construed to permit any act, waiver, surrender or restriction adversely affecting any bonds then outstanding hereunder.

Without limiting the generality of the foregoing, if the Trust Indenture Act of 1939, as in effect at any time and from time to time,

(i)shall require one or more changes to any provisions hereof or the inclusion herein of any additional provisions, or shall by operation of law be deemed to effect such changes or incorporate such provisions by reference or otherwise, this Indenture shall be deemed to have been amended so as to conform to the Trust Indenture Act as then in effect, and the Company and the Trustee may, without the consent of any holders of bonds, enter into an indenture supplemental hereto to evidence such amendment hereof; or

(ii)shall permit one or more changes to, or the elimination of, any provisions hereof which shall theretofore have been required by the Trust Indenture Act of 1939 to be contained herein or are contained herein to reflect any provisions of the Trust Indenture Act of 1939, this Indenture shall be deemed to have been amended to effect such changes or elimination, and the Company and the Trustee may, without the consent of any holders of bonds, enter into an indenture supplemental hereto to evidence such amendment hereof.

ARTICLE VIIIMISCELLANEOUS

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SECTION 8.1Provisions Required by Trust Indenture Act of 1939 to Control. If and to the extent that any provision hereof, or any other provision of the Mortgage, limits, qualifies, or conflicts with another provision included in the Mortgage which is required to be included in the Mortgage by any of Sections 310 to 317, inclusive, of the Trust Indenture Act of 1939, as amended by the Trust Indenture Reform Act of 1990, through operation of Section 318(c) thereof, such required provisions shall control.

SECTION 8.2Acceptance of Trust. The Trustee hereby accepts the trust hereby declared and provided and agrees to perform the same upon the terms and conditions in the Original Indenture and in this Thirty-First Supplemental Indenture set forth.

SECTION 8.3This Indenture Part of Original Indenture. This Thirty-First Supplemental Indenture is executed and shall be construed as an indenture supplemental to the Original Indenture and shall form a part thereof.

SECTION 8.4Execution in Any Number of Counterparts. This Thirty-First Supplemental Indenture may be simultaneously executed in any number of counterparts, each of which, when so executed, shall be deemed to be an original; such counterparts shall together constitute but one and the same instrument.

SECTION 8.5Date of Execution. Although this Thirty-First Supplemental Indenture is dated, for convenience and for purposes of reference, as of March 15, 2013, the actual dates of execution by the Company and by the Trustee are as indicated by their respective acknowledgements hereto annexed.

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IN WITNESS WHEREOF, Laclede Gas Company, party of the first part, has caused its corporate name to be hereunto affixed and this instrument to be signed and sealed by its President, a Vice President, or Treasurer and its corporate seal to be attested by its Secretary or an Assistant Secretary, for and in its behalf; and UMB Bank & Trust, n.a., Trustee, party of the second part, in token of its acceptance of the trust hereby created, has caused its name to be hereunto affixed and this instrument to be signed and sealed by a Vice President or an Assistant Vice President, and its seal to be attested by its Secretary or an Assistant Secretary.

	LACLEDE GAS COMPANY
	By	/s/ Lynn D. Rawlings
		Lynn D. Rawlings
		Treasurer and Assistant Secretary
ATTEST:
/s/ Mary C. Kullman
Mary C. Kullman
Corporate Secretary
(SEAL)
	UMB BANK & TRUST, N.A.
	Trustee
	By	/s/ Victor Zarrilli
		Sr. Vice President
ATTEST:
/s/ Richard F. Novosak
Assistant Secretary
(SEAL)

[Signature page to Thirty-First Supplemental Indenture]

State of Missouri	)
	)	ss.
City of St. Louis	)

On this 8th day of March, 2013 before me appeared Lynn D. Rawlings, to me personally known, who, being by me duly sworn did say that she is the Treasurer and Assistant Secretary of Laclede Gas Company, the corporation described in and which executed the foregoing instrument, and that the seal affixed to the foregoing instrument is the corporate seal of said corporation and that said instrument was signed and sealed in behalf of said corporation by authority of its board of directors, and said Mary C. Kullman acknowledged said instrument to be the free act and deed of said corporation.

IN WITNESS WHEREOF, I have hereunto set my hand and affixed my official seal in my office in the City of St. Louis, Missouri, the day and year last above written.

My commission expires         11-7-2015            .

/s/ Lisa M. Reed                
Notary Public
State of Missouri

(SEAL)

[Signature page to Thirty-First Supplemental Indenture]

State of Missouri	)
	)	ss.
City of St. Louis	)

On this 8th day of March, 2013 before me appeared Victor Zarrilli to me personally known, who, being by me duly sworn did say that (s)he is a Senior Vice President of UMB Bank & Trust, n.a., the national banking association described in and which executed the foregoing instrument, and that the seal affixed to the foregoing instrument is the seal of said association and that said instrument was signed and sealed in behalf of said association by authority of its board of directors, and said Victor Zarrilli acknowledged said instrument to be the free act and deed of said association.

IN WITNESS WHEREOF, I have hereunto set my hand and affixed my official seal in my office in the City of St. Louis, Missouri, the day and year last above written.

My commission expires         11-7-2015            .

/s/ Lisa M. Reed                
Notary Public
State of Missouri

(SEAL)

[Signature page to Thirty-First Supplemental Indenture]

EX-12

Exhibit 12

THE LACLEDE GROUP, INC. AND SUBSIDIARY COMPANIES

SCHEDULE OF COMPUTATION OF RATIO OF EARNINGS TO FIXED CHARGES

	Twelve Months Ended
	Mar. 31,		September 30,
(Thousands of Dollars)	2013		2012		2011		2010		2009		2008
Income from continuing      operations before interest
charges and income taxes	$	113,225	$	113,875	$	118,424	$	107,986	$	126,517	$	113,228
Add: One third of applicable
rentals charged to operating
expense (which approximates
the interest factor)	1,710		1,591		1,799		1,825		1,833		1,691
Total Earnings	$	114,935	$	115,466	$	120,223	$	109,811	$	128,350	$	114,919
Interest on long-term debt	$	22,605	$	22,958	$	23,161	$	24,583	$	24,583	$	19,851
Other interest	2,477		1,988		2,256		2,269		5,163		9,626
Add: One third of applicable
rentals charged to operating
expense (which approximates
the interest factor)	1,710		1,591		1,799		1,825		1,833		1,691
Total Fixed Charges	$	26,792	$	26,537	$	27,216	$	28,677	$	31,579	$	31,168
Ratio of Earnings to Fixed
Charges	4.29		4.35		4.42		3.83		4.06		3.69

EX-31

Exhibit 31

CERTIFICATION

I, Suzanne Sitherwood, 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:	April 30, 2013	Signature:	/s/ Suzanne Sitherwood
			Suzanne Sitherwood
			President and Chief Executive Officer

CERTIFICATION

I, Mark D. Waltermire, certify that:

1. I have reviewed this quarterly report on Form 10-Q of The Laclede Group, Inc.;

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

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

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

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

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

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

d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (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:	April 30, 2013	Signature:	/s/ Mark D. Waltermire
			Mark D. Waltermire
			Executive Vice President, Chief Financial Officer

EX-32

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, Suzanne Sitherwood, President and Chief Executive Officer of The Laclede Group, Inc., hereby certify that

(a) To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2013 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

(b) To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the quarter ended March 31, 2013 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.

Date:	April 30, 2013	/s/ Suzanne Sitherwood
		Suzanne Sitherwood
		President and Chief Executive Officer

Section 1350 Certification

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

a. To the best of my knowledge, the accompanying report on Form 10-Q for the quarter ended March 31, 2013 fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934, and

b. To the best of my knowledge, the information contained in the accompanying report on Form 10-Q for the quarter ended March 31, 2013 fairly presents, in all material respects, the financial condition and results of operations of The Laclede Group, Inc.

Date:	April 30, 2013	/s/ Mark D. Waltermire
		Mark D. Waltermire
		Executive Vice President, Chief Financial Officer

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CONCENTRATIONS OF CREDIT RISK (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Mar. 31, 2013
Concentration Risk [Line Items]
Number of large counterparties for which credit risk is disclosed	5
Number of investment-grade rated counterparties for which credit risk is disclosed, in terms of net accounts receivable exposure	5
Energy Producers And Their Affiliates [Member]
Concentration Risk [Line Items]
Accounts receivable	21.9
Net receivable amount	19.5
Utility Companies And Their Affiliates [Member]
Concentration Risk [Line Items]
Accounts receivable	13.7
Net receivable amount	11.6
Largest Counterparties [Member]
Concentration Risk [Line Items]
Accounts receivable	23.9
Net receivable amount	22.4

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EARNINGS PER COMMON SHARE (Details) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012
Basic EPS [Abstract]
Net Income	$ 30,242	$ 29,684	$ 55,810	$ 54,858
Less: Income allocated to participating securities	186	167	312	324
Net Income Available to Common Shareholders, Basic	30,056	29,517	55,498	54,534
Weighted Average Shares Outstanding, Basic	22,421	22,254	22,396	22,223
Earnings Per Share of Common Stock, Basic (Per Share)	$ 1.34	$ 1.33	$ 2.48	$ 2.45
Diluted EPS [Abstract]
Net Income	30,242	29,684	55,810	54,858
Less: Income allocated to participating securities	186	166	311	323
Net Income Available to Common Stockholders, Diluted	$ 30,056	$ 29,518	$ 55,499	$ 54,535
Weighted Average Shares Outstanding, Basic	22,421	22,254	22,396	22,223
Dilutive Effect of Stock Options, Restricted Stock, and Restricted Stock Units	77	82	70	76
Weighted Average Diluted Shares	22,498	22,336	22,466	22,299
Earnings Per Share of Common Stock, Diluted (Per share)	$ 1.34	$ 1.32	$ 2.47	$ 2.45
Restricted Stock and Stock Units Subject to Performance and/or Market Conditions [Member]
Antidilutive Securities Excluded from Computation of Earnings Per Share [Line Items]
Outstanding shares excluded from the calculation of diluted EPS	211	203	211	203

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Tables)

6 Months Ended

Mar. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative Instruments and Hedging Activities

Open NYMEX/ICE natural gas futures and swap positions at March 31, 2013 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 2013	—	$	—	4.36	$	3.61
Fiscal 2014	—	—		3.26	3.86
Open long futures positions
Fiscal 2013	7.58	$	3.40	0.77	$	3.71
Fiscal 2014	4.87	3.97		0.65	3.01

The Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income

The Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income
		Three Months Ended						Six Months Ended
	Location of Gain (Loss)	March 31,						March 31,
(Thousands)	Recorded in Income	2013			2012			2013			2012
Derivatives in Cash Flow Hedging Relationships
Effective portion of gain (loss) recognized in OCI on derivatives:
NYMEX/ICE natural gas contracts		$	(3,188	)	$	5,023		$	(1,855	)	$	8,020
NYMEX gasoline and heating oil contracts		147			83			203			133
Interest rate swaps		(4,549		)	—			(4,549		)	—
Total		$	(7,590	)	$	5,106		$	(6,201	)	$	8,153
Effective portion of gain (loss) reclassified from AOCI to income:
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	$	302		$	4,048		$	(1,661	)	$	10,788
	Gas Marketing Operating Expenses	(318		)	(4,445		)	(652		)	(8,369		)
Sub-total		(16		)	(397		)	(2,313		)	2,419
NYMEX gasoline and heating oil contracts	Other Gas Utility Operating Expenses	38			(11		)	85			3
Total		$	22		$	(408	)	$	(2,228	)	$	2,422
Ineffective portion of gain (loss) on derivatives recognized in income:
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	$	(87	)	$	50		$	(412	)	$	69
	Gas Marketing Operating Expenses	(44		)	(90		)	(129		)	(196		)
Sub-total		(131		)	(40		)	(541		)	(127		)
NYMEX gasoline and heating oil contracts	Other Gas Utility Operating Expenses	(31		)	28			(132		)	34
Total		$	(162	)	$	(12	)	$	(673	)	$	(93	)
Derivatives Not Designated as Hedging Instruments *
Gain (loss) recognized in income on derivatives:
Natural gas commodity contracts	Gas Marketing Operating Revenues	$	1,745		$	1,557		$	775		$	790
	Gas Marketing Operating Expenses	—			—			—			687
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	(1,679		)	1,478			(612		)	1,548
	Gas Marketing Operating Expenses	—			30			—			30
NYMEX gasoline and heating oil contracts	Other Income and (Income Deductions) - Net	13			12			46			13
Total		$	79		$	3,077		$	209		$	3,068

* 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 Gas 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

Fair Value of Derivative Instruments in the Consolidated Balance Sheet at March 31, 2013
	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	Accounts Receivable - Other	$	520		Accounts Receivable - Other	$	2,993
NYMEX/ICE natural gas contracts	Other Deferred Charges	5			Other Deferred Charges	—
NYMEX gasoline and heating oil contracts	Derivative Instrument Assets	312			Derivative Instrument Assets	—
Interest rate swaps	Other Current Liabilities	—			Other Current Liabilities	4,549
Sub-total		837				7,542
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Derivative Instrument Assets	10,862			Derivative Instrument Assets	339
	Accounts Receivable – Other	2			Accounts Receivable – Other	457
Natural gas commodity contracts	Derivative Instrument Assets	2,943			Derivative Instrument Assets	227
	Other Current Liabilities	62			Other Current Liabilities	787
NYMEX gasoline and heating oil contracts	Derivative Instrument Assets	10			Derivative Instrument Assets	—
Sub-total		13,879				1,810
Total derivatives		$	14,716			$	9,352
Fair Value of Derivative Instruments in the Consolidated Balance Sheet at September 30, 2012
	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	Accounts Receivable - Other	$	405		Accounts Receivable - Other	$	3,413
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	334			Accounts Receivable - Other	—
Sub-total		739				3,413
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Accounts Receivable - Other	8,000			Accounts Receivable - Other	10,731
Natural gas commodity contracts	Derivative Instrument Assets	3,150			Derivative Instrument Assets	295
	Other Current Liabilities	4			Other Current Liabilities	137
	Other Deferred Charges	19			Other Deferred Charges	—
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	10			Accounts Receivable - Other	—
Sub-total		11,183				11,163
Total derivatives		$	11,922			$	14,576

Fair Value of Derivative Instruments in the Consolidated Balance Sheet at March 31, 2012
	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	$	3,545		Derivative Instrument Assets	$	3,242
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	72			Accounts Receivable - Other	—
Sub-total		3,617				3,242
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Accounts Receivable - Other	709			Accounts Receivable - Other	36,437
	Derivative Instrument Assets	2,238			Derivative Instrument Assets	474
Natural gas commodity contracts	Derivative Instrument Assets	4,176			Derivative Instrument Assets	490
	Other Deferred Charges	217			Other Deferred Charges	—
	Other Current Liabilities	48			Other Current Liabilities	721
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	9			Accounts Receivable - Other	—
Sub-total		7,397				38,122
Total derivatives		$	11,014			$	41,364

* 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.

Derivative instrument Reconciliation

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

(Thousands)	Mar. 31, 2013			Sept. 30, 2012			Mar. 31, 2012
Fair value of asset derivatives presented above	$	14,716		$	11,922		$	11,014
Fair value of cash margin receivables offset with derivatives	2,928			5,478			35,648
Netting of assets and liabilities with the same counterparty	(11,618		)	(14,526		)	(41,148		)
Total	$	6,026		$	2,874		$	5,514
Derivative Instrument Assets, per Consolidated Balance Sheets:
Derivative instrument assets	$	6,021		$	2,855		$	5,297
Other deferred charges	5			19			217
Total	$	6,026		$	2,874		$	5,514
Fair value of liability derivatives presented above	$	9,352		$	14,576		$	41,364
Fair value of cash margin payables offset with derivatives	7,540			83			457
Netting of assets and liabilities with the same counterparty	(11,618		)	(14,526		)	(41,148		)
Derivative instrument liabilities, per Consolidated Balance Sheets*	$	5,274		$	133		$	673

*    Included in the Other line of the Current Liabilities section

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COMMITMENTS AND CONTINGENCIES (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended	3 Months Ended		3 Months Ended
	Mar. 31, 2013	Jun. 30, 2013 Laclede Gas [Member]	Apr. 29, 2013 Laclede Gas [Member]	Jun. 30, 2013 LER [Member]	Apr. 29, 2013 LER [Member]
Commitments [Abstract]
Minimum total payments required for natural gas contracts	$ 410
Approximate contract amount of project	1.5
Contingencies and Indemnifications [Abstract]
Number Of Former Manufactured Gas Plant Sites In Missouri	3
Number of former manufactured gas plant (MGP) sites in Shrewsbury, Missouri	1
Number of former manufactured gas plant (MGP) sites in the City of St. Louis	2
Minimum cost estimate for a one-time contractual transfer of risk	5.8
Maximum cost estimate for a one-time contractual transfer of risk	36.3
Proposed disallowance amount related to purchase gas costs	6.0
Proceeds from Other Deposits - Brokerage		0.7		0.1
Amount Remaining On Deposit With Brokerage Firm			$ 0.9		$ 0.2

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Part 2) (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Sep. 30, 2012	Mar. 31, 2012
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	$ 14,716	$ 11,922	$ 11,014
Derivative Liability, Fair Value, Gross Liability	9,352	14,576	41,364
NYMEX Natural Gas Contracts [Member] | Designated as Hedging Instrument [Member] | Derivative Instruments Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset			3,545
Derivative Liability, Fair Value, Gross Liability			3,242
NYMEX Natural Gas Contracts [Member] | Designated as Hedging Instrument [Member] | Other Deferred Charges [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	5
Derivative Liability, Fair Value, Gross Liability	0
NYMEX Natural Gas Contracts [Member] | Designated as Hedging Instrument [Member] | Accounts Receivable Other [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	520	405
Derivative Liability, Fair Value, Gross Liability	2,993	3,413
NYMEX Natural Gas Contracts [Member] | Not Designated as Hedging Instrument [Member] | Derivative Instruments Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	10,862		2,238
Derivative Liability, Fair Value, Gross Liability	339		474
NYMEX Natural Gas Contracts [Member] | Not Designated as Hedging Instrument [Member] | Accounts Receivable Other [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	2	8,000	709
Derivative Liability, Fair Value, Gross Liability	457	10,731	36,437
Natural Gas Commodity Contracts [Member] | Not Designated as Hedging Instrument [Member] | Derivative Instruments Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	2,943	3,150	4,176
Derivative Liability, Fair Value, Gross Liability	227	295	490
Natural Gas Commodity Contracts [Member] | Not Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	62	4	48
Derivative Liability, Fair Value, Gross Liability	787	137	721
Natural Gas Commodity Contracts [Member] | Not Designated as Hedging Instrument [Member] | Other Deferred Charges [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		19	217
Derivative Liability, Fair Value, Gross Liability		0	0
NYMEX Gasoline and Heating Oil Contracts [Member] | Designated as Hedging Instrument [Member] | Derivative Instruments Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	312
Derivative Liability, Fair Value, Gross Liability	0
NYMEX Gasoline and Heating Oil Contracts [Member] | Designated as Hedging Instrument [Member] | Accounts Receivable Other [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		334	72
Derivative Liability, Fair Value, Gross Liability		0	0
NYMEX Gasoline and Heating Oil Contracts [Member] | Not Designated as Hedging Instrument [Member] | Derivative Instruments Assets [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	10
Derivative Liability, Fair Value, Gross Liability	0
NYMEX Gasoline and Heating Oil Contracts [Member] | Not Designated as Hedging Instrument [Member] | Accounts Receivable Other [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset		10	9
Derivative Liability, Fair Value, Gross Liability		0	0
Interest Rate Swap [Member] | Designated as Hedging Instrument [Member] | Other Current Liabilities [Member]
Derivatives, Fair Value [Line Items]
Derivative Asset, Fair Value, Gross Asset	0
Derivative Liability, Fair Value, Gross Liability	$ 4,549

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STOCK-BASED COMPENSATION

6 Months Ended

Mar. 31, 2013

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

STOCK-BASED COMPENSATION

3.        STOCK-BASED COMPENSATION

Awards of stock-based compensation are made pursuant to The Laclede Group 2006 Equity Incentive Plan (2006 Plan). Refer to Note 3 of the Consolidated Financial Statements included in the Company’s Form 10-K for the fiscal year ended September 30, 2012 for descriptions of the plan.

Restricted Stock Awards

During the six months ended March 31, 2013, the Company granted 108,419 performance-contingent restricted stock units to executive officers and key employees at a weighted average grant date fair value of $34.48 per share. This number represents the maximum shares that can be earned pursuant to the terms of the awards. Most of these stock units have a performance period ending September 30, 2015. While the participants have no interim voting rights on these stock units, dividends accrue during the performance period and are paid to the participants upon vesting, but are subject to forfeiture if the underlying stock units do not vest. The number of stock 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 GAAP.

Activity of restricted stock and restricted stock units subject to performance and/or market conditions during the six months ended March 31, 2013 is presented below:

	Restricted Stock/ Stock Units		Weighted Average Grant Date Fair Value
Nonvested at September 30, 2012	232,403		$	30.89
Granted (maximum shares that can be earned)	108,419		$	34.48
Vested	(37,436	)	$	27.02
Forfeited	(48,782	)	$	25.71
Nonvested at March 31, 2013	254,604		$	33.98

During the six months ended March 31, 2013, the Company granted 58,774 shares of time-vested restricted stock and stock units to executive officers, key employees, and directors at a weighted average grant date fair value of $39.96 per share. Most of these shares were awarded on December 3, 2012 and vest December 3, 2015. In the interim, participants receive full voting rights and dividends, which are not subject to forfeiture.

Time-vested restricted stock and stock unit activity for the six months ended March 31, 2013 is presented below:

	Restricted Stock/ Stock Units		Weighted Average Grant Date Fair Value
Nonvested at September 30, 2012	115,115		$	36.54
Granted	58,774		$	39.96
Vested	(20,200	)	$	30.46
Forfeited	(3,250	)	$	38.18
Nonvested at March 31, 2013	150,439		$	38.65

During the six months ended March 31, 2013, 57,636 shares of restricted stock and stock units (performance-contingent and time-vested), awarded on November 4, 2009, December 1, 2009, and January 4, 2010, vested. The Company withheld 18,744 of the vested shares at a weighted average price of $38.90 per share pursuant to elections by employees to satisfy tax withholding obligations.

Stock Option Awards

Stock option activity for the six months ended March 31, 2013 is presented below:

	Stock Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (Years)	Aggregate Intrinsic Value ($000)
Outstanding at September 30, 2012	214,000		$	31.02
Granted	—		$	—
Exercised	(49,500	)	$	29.54
Forfeited	—		$	—
Expired	—		$	—
Outstanding at March 31, 2013	164,500		$	31.47	2.1	$	1,848
Fully Vested and Expected to Vest at March 31, 2013	164,500		$	31.47	2.1	$	1,848
Exercisable at March 31, 2013	164,500		$	31.47	2.1	$	1,848

The closing price of the Company’s common stock was $42.70 at March 31, 2013.

Equity Compensation Costs

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

	Three Months Ended March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013			2012
Total equity compensation cost	$	1,137		$	684		$	1,759		$	1,351
Compensation cost capitalized	(356		)	(221		)	(539		)	(359		)
Compensation cost recognized in net income	781			463			1,220			992
Income tax benefit recognized in net income	(298		)	(179		)	(467		)	(383		)
Compensation cost recognized in net income, net of income tax	$	483		$	284		$	753		$	609

As of March 31, 2013, there was $7.1 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 2.2 years.

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ACQUISITION AGREEMENTS (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended	6 Months Ended
	Mar. 31, 2013	Mar. 31, 2013
Business Combinations [Line Items]
Pending Business Acquisition, Stated Purchase Price, Total	$ 1,035	$ 1,035
Bridge Loan	1,020	1,020
Acquisition Related Costs	1.7	3.9
Reverse break up fee	73.1	73.1
Number of Banks	9	9
Missouri Gas Energy (MGE) [Member]
Business Combinations [Line Items]
Pending Business Acquisition, Stated Purchase Price, Total	975	975
New England Gas Company (NEG) [Member]
Business Combinations [Line Items]
Pending Business Acquisition, Stated Purchase Price, Total	60	60
Pending Business Acquisition, Debt to be Assumed	19.5	19.5
Pending Business Acquisition, Cash Deposited	3.0	3.0
Pending Business Acquisition, Cash to be Received	$ 11	$ 11

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Part 2 (Details) (USD $) In Millions, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012
Accounting Policies [Abstract]
Gross Receipts taxes recorded in gas utility operating revenues	$ 17.2	$ 15.5	$ 27.5	$ 25.7

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES Part 1 (Details) (USD $) In Millions, unless otherwise specified	Mar. 31, 2013	Sep. 30, 2012	Mar. 31, 2012
Accounting Policies [Abstract]
Accrued Unbilled Revenue	$ 33.3	$ 11.6	$ 13.0

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 1 (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012
Pension Plans [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost - benefits earned during the period	$ 2,311	$ 2,301	$ 4,622	$ 4,613
Interest Cost	4,066	4,840	8,132	9,711
Expected return on plan assets	(4,741)	(4,899)	(9,482)	(9,798)
Amortization of prior service cost (credit)	136	148	272	296
Amortization of actuarial loss	2,839	2,259	5,678	4,536
Loss on lump-sum settlement	0	3,407	0	3,407
Sub-total	4,611	8,056	9,222	12,765
Regulatory adjustment	(433)	(484)	(867)	(967)
Net benefit cost	4,178	7,572	8,355	11,798
Postretirement Benefit [Member]
Defined Benefit Plans and Other Postretirement Benefit Plans Table Text Block [Line Items]
Service cost - benefits earned during the period	2,534	2,015	5,067	4,030
Interest Cost	1,279	1,380	2,558	2,760
Expected return on plan assets	(1,081)	(991)	(2,162)	(1,982)
Amortization of transition obligation	23	34	46	68
Amortization of prior service cost (credit)	1	(518)	2	(1,036)
Amortization of actuarial loss	1,325	1,065	2,650	2,130
Sub-total	4,081	2,985	8,161	5,970
Regulatory adjustment	(1,699)	(604)	(3,398)	(1,208)
Net benefit cost	$ 2,382	$ 2,381	$ 4,763	$ 4,762

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS Part 2 (Details) (USD $) In Millions, unless otherwise specified	6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Dec. 31, 2010
Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]
Extent of Lump-sum payments recognized, percentage	100%
Lump-sum payments recognized as settlements		$ 6.4
Implementation period used to calculate return on plan assets (in years)	four-year
Gains or losses includible in cost amortized to extent exceeds benefit obligations or market-related value of plan assets, percentage	10.00%
Recovery in rates for the qualified pension plans base allowance			15.5
Recovery in rates for postretirement benefit			9.5
Defined Benefit Plan, Pension Plans, Qualified Trusts, Contributions by Employer, Fiscal Year To Date	8.9
Defined Benefit Plan, Pension Plans, Non-Qualified Plans, Contributions by Emplyer, Fiscal Year To Date	0.3
Defined Benefit Plan, Pension Plans, Qualified Trusts, Estimated Future Employer Contributions Remaining For Current Fiscal Year, Description	14.5
Defined Benefit Plan, Pension Plans, Non-Qualified Trusts, Estimated Future Employer Contributions Remaining For Current Fiscal Year, Description	0.8
Medical insurance available until age is reached after early retirement	65
Amortization period for transition obligation excluded from postretirement benefit cost (in years)	20 years
Defined Benefit Plan, Other Postretirement Benefit Plans, Non-Qualified Plans, Contributions by Employer, Fiscal Year To Date	0.4
Defined Benefit Plan, Other Postretirement Benefit Plans, Qualified Trusts, Contributions by Employer, Fiscal Year to Date	4.1
Defined Benefit Plan, Other Postretirement Benefit Plans, Qualified Trusts, Estimated Future Employer Contributions Remaining For Current Fiscal Year, Description	12.2
Defined Benefit Plan, Other Postretirement Benefit Plans, Estimated Future Payment Directly Participants, Description	$ 0.4

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

6 Months Ended

Mar. 31, 2013

Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]

PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS

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 a growth segment consisting of exposure to equity markets, commodities, real estate and inflation-indexed securities, achieved through derivative instruments.

Pension costs for quarters ended March 31, 2013 and 2012 were $4.2 million and $7.6 million, respectively, including amounts charged to construction. Pension costs for six months ended March 31, 2013 and 2012 were $8.4 million and $11.8 million, respectively, including amounts charged to construction.

The net periodic pension costs include the following components:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2013			2012			2013			2012
Service cost – benefits earned during the period	$	2,311		$	2,301		$	4,622		$	4,613
Interest cost on projected benefit obligation	4,066			4,840			8,132			9,711
Expected return on plan assets	(4,741		)	(4,899		)	(9,482		)	(9,798		)
Amortization of prior service cost	136			148			272			296
Amortization of actuarial loss	2,839			2,259			5,678			4,536
Loss on lump-sum settlement	—			3,407			—			3,407
Sub-total	4,611			8,056			9,222			12,765
Regulatory adjustment	(433		)	(484		)	(867		)	(967		)
Net pension cost	$	4,178		$	7,572		$	8,355		$	11,798

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. There were no lump-sum payments recognized as settlements during the six months ended March 31, 2013. Lump-sum payments recognized as settlements were $6.4 million during the six months ended March 31, 2012.

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 $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 2013 contributions to the pension plans through March 31, 2013 were $8.9 million to the qualified trusts and approximately $0.3 million to the non-qualified plans. Contributions to the pension plans for the remaining six months of fiscal 2013 are anticipated to be at least $14.5 million to the qualified trusts and $0.8 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 both the quarters ended March 31, 2013 and 2012 were $2.4 million, including amounts charged to construction. Postretirement benefit costs for both the six months ended March 31, 2013 and 2012 were $4.8 million, including amounts charged to construction.

Net periodic postretirement benefit costs consisted of the following components:

	Three Months Ended March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013			2012
Service cost – benefits earned during the period	$	2,534		$	2,015		$	5,067		$	4,030
Interest cost on accumulated postretirement benefit obligation	1,279			1,380			2,558			2,760
Expected return on plan assets	(1,081		)	(991		)	(2,162		)	(1,982		)
Amortization of transition obligation	23			34			46			68
Amortization of prior service cost (credit)	1			(518		)	2			(1,036		)
Amortization of actuarial loss	1,325			1,065			2,650			2,130
Sub-total	4,081			2,985			8,161			5,970
Regulatory adjustment	(1,699		)	(604		)	(3,398		)	(1,208		)
Net postretirement benefit cost	$	2,382		$	2,381		$	4,763		$	4,762

Missouri state law provides for the recovery in rates of costs accrued pursuant to 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 $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 2013 contributions to the postretirement plans through March 31, 2013 were $4.1 million to the qualified trusts and approximately $0.4 million paid directly to participants from Laclede Gas' funds. Contributions to the postretirement plans for the remaining six months of fiscal year 2013 are anticipated to be $12.2 million to the qualified trusts and $0.4 million paid directly to participants from Laclede Gas’ funds.

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STOCK-BASED COMPENSATION (Details) (USD $)	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013 Restricted Stock Awards [Member]	Mar. 31, 2013 Restricted Stock Awards [Member] Time Vested Restricted Stock and Time Vested Restricted Stock Units [Member]	Mar. 31, 2013 Restricted Stock Awards [Member] Executive Officers and Key Employees [Member] Performance Contingent Restricted Stock and Stock Units [Member]	Mar. 31, 2013 Restricted Stock Awards [Member] Executive Officers and Key Employees [Member] Time Vested Restricted Stock and Time Vested Restricted Stock Units [Member]	Mar. 31, 2013 Stock Options Awards [Member]	Sep. 30, 2012 Stock Options Awards [Member]
Restricted Stock Awards [Abstract]
Granted (in shares)						58,774	108,419	58,774
Granted, weighted average grant date fair value (per share)						$ 39.96	$ 34.48	$ 39.96
Vested restricted stock withheld for tax withholding obligations (in shares)					18,744
Vested restricted stock withheld for tax withholding obligations, weighted average price (in dollars per share)					$ 38.90
Restricted stock/stock units activity [Roll-Forward]
Nonvested, beginning of period (in shares)						115,115	232,403
Granted (in shares)						58,774	108,419	58,774
Vested (in shares)					(57,636)	(20,200)	(37,436)
Forfeited (in shares)						(3,250)	(48,782)
Nonvested, end of period (in shares)						150,439	254,604
Weighted average Grant Date Fair Value [Abstract]
Nonvested Beginning Balance, weighted average grant date fair value (per share)						$ 36.54	$ 30.89
Granted, weighted average grant date fair value (per share)						$ 39.96	$ 34.48	$ 39.96
Vested, weighted average grant date fair value (per share)						$ 30.46	$ 27.02
Forfeited, weighted average grant date fair value (per share)						$ 38.18	$ 25.71
Nonvested Ending Balance, weighted average grant date fair value (per share)						$ 38.65	$ 33.98
Stock Options - Shares [Roll Forward]
Outstanding Balance - stock options									164,500	214,000
Fully Vested and Expected to Vest, end of period (in shares)									164,500
Exercisable, end of period (in shares)									164,500
Granted - stock options (in shares)									0
Exercised - stock options (in shares)									(49,500)
Forfeited - stock options (in shares)									0
Expired - stock options (in shares)									0
Stock Options - Shares Weighted Average Exercise Price [Abstract]
Outstanding Beginning Balance, weighted average exercise price - stock options (per share)									$ 31.47	$ 31.02
Granted, weighted average exercise price - stock options (per share)									$ 0.00
Exercised, weighted average exercise price - stock options (per share)									$ 29.54
Forfeited, weighted average exercise price - stock options (per share)									$ 0.00
Expired, weighted average exercise price - stock options (per share)									$ 0.00
Outstanding Ending Balance, weighted average exercise price - stock options (per share)									$ 31.47	$ 31.02
Fully Vested and Expected to Vest at End of Period, weighted average exercise price - stock options (per share)									$ 31.47
Exercisable at End of Period, weighted average exercise price - stock options (per share)									$ 31.47
Outstanding Ending Balance, weighted average remaining contractual term - stock options (in years)									2 years 1 month 6 days
Fully Vested and Expected to Vest at End of Period, weighted average remaining contractual term - stock options (in years)									2 years 1 month 6 days
Exercisable at End of Period, weighted average remaining contractual term - stock options (in years)									2 years 1 month 6 days
Outstanding Ending Balance, aggregate intrinsic value - stock options									$ 1,848,000
Fully Vested and Expected to Vest at End of Period, aggregate intrinsic value - stock options									1,848,000
Exercisable at End of Period, aggregate intrinsic value - stock options									1,848,000
Stock Option Awards [Abstract]
Common stock closing price (per share)									$ 42.70
Equity Compensation Cost [Abstract]
Total equity compensation cost	1,137,000	684,000	1,759,000	1,351,000
Compensation cost capitalized	(356,000)	(221,000)	(539,000)	(359,000)
Compensation cost recognized in net income	781,000	463,000	1,220,000	992,000
Income tax benefit recognized in net income	(298,000)	(179,000)	(467,000)	(383,000)
Compensation cost recognized in net income, net of income tax	483,000	284,000	753,000	609,000
Total unrecognized compensation cost	$ 7,100,000		$ 7,100,000
Weighted average period cost to be recognized (in years)	2 years 2 months 13 days

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OTHER INCOME AND (INCOME DEDUCTIONS) - NET (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012
Other Nonoperating Income (Expense) [Abstract]
Interest income	$ 257	$ 316	$ 663	$ 664
Net investment gain	1,174	1,164	1,104	2,194
Other income	9	11	77	11
Other income deductions	(100)	(110)	580	451
Other Income and (Income Deductions) - Net	$ 1,340	$ 1,381	$ 2,424	$ 3,320

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STATEMENTS OF CONSOLIDATED INCOME (UNAUDITED) (USD $) In Thousands, except Per Share data, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012
Operating Revenues:
Gas Utility	$ 354,097	$ 298,620	$ 604,208	$ 549,522
Gas Marketing	41,255	59,434	96,504	218,022
Other	2,261	121	3,904	1,544
Total Operating Revenues	397,613	358,175	704,616	769,088
Gas Utility
Natural and propane gas	230,440	171,164	366,956	317,915
Other operation expenses	35,267	38,043	69,187	75,608
Maintenance	5,924	5,761	11,655	11,069
Depreciation and amortization	11,258	10,175	22,223	20,264
Taxes, other than income taxes	21,751	20,093	36,557	34,760
Total Gas Utility Operating Expenses	304,640	245,236	506,578	459,616
Gas Marketing	35,995	61,805	93,376	214,364
Other	5,129	551	10,727	1,420
Total Operating Expenses	345,764	307,592	610,681	675,400
Operating Income	51,849	50,583	93,935	93,688
Other Income and (Income Deductions) - Net	1,340	1,381	2,424	3,320
Interest Charges:
Interest on long-term debt	5,689	5,740	11,127	11,479
Other interest charges	1,016	539	1,604	1,114
Total Interest Charges	6,705	6,279	12,731	12,593
Income Before Income Taxes	46,484	45,685	83,628	84,415
Income Tax Expense	16,242	16,001	27,818	29,557
Net Income	$ 30,242	$ 29,684	$ 55,810	$ 54,858
Weighted Average Number of Common Shares Outstanding:
Basic	22,421	22,254	22,396	22,223
Diluted	22,498	22,336	22,466	22,299
Basic Earnings Per Share of Common Stock:
Basic Earnings Per Share of Common Stock	$ 1.34	$ 1.33	$ 2.48	$ 2.45
Diluted Earnings Per Share of Common Stock:
Diluted Earnings Per Share of Common Stock	$ 1.34	$ 1.32	$ 2.47	$ 2.45
Dividends Declared Per Share of Common Stock	$ 0.425	$ 0.415	$ 0.850	$ 0.830

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STATEMENTS OF CONSOLIDATED CASH FLOWS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012
Operating Activities:
Net Income	$ 55,810	$ 54,858
Adjustments to reconcile net income to net cash provided by (used in) operating activities:
Depreciation, amortization, and accretion	22,913	20,565
Deferred income taxes and investment tax credits	(11,132)	6,167
Other - net	450	(744)
Changes in assets and liabilities:
Accounts receivable - net	(71,164)	(20,355)
Unamortized purchased gas adjustments	29,635	14,478
Deferred purchased gas costs	43,827	(30,160)
Accounts payable	23,797	(26,546)
Delayed customer billings - net	(44,809)	(28,694)
Taxes accrued	32,971	12,575
Natural gas stored underground	59,953	57,714
Other assets and liabilities	115	11,601
Net cash provided by (used in) operating activities	142,366	71,459
Investing Activities:
Capital expenditures	(62,707)	(40,658)
Other investments	(2,126)	(1,440)
Net cash used in investing activities	(64,833)	(42,098)
Financing Activities:
Issuance of long-term debt	125,000	0
Maturity of first mortgage bonds	(25,000)	0
Repayment of short-term debt - net	(40,100)	(46,000)
Non-employee directors' restricted stock awards	0	(565)
Changes in book overdrafts	(1,262)	357
Issuance of common stock	2,852	2,195
Dividends paid	(19,054)	(18,314)
Employees' taxes paid associated with restricted shares withheld upon vesting	(729)	(1,165)
Excess tax benefits from stock-based compensation	636	185
Other	(453)	(29)
Net cash provided by financing activities	41,890	(63,336)
Net Increase (Decrease) in Cash and Cash Equivalents	119,423	(33,975)
Cash and Cash Equivalents at Beginning of Period	27,457	43,277
Cash and Cash Equivalents at End of Period	146,880	9,302
Supplemental Disclosure of Cash Paid (Refunded) During the Period for:
Interest	14,569	12,521
Income taxes	$ (3,165)	$ 2,763

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FAIR VALUE MEASUREMENTS (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Quoted Prices in Active Markets (Level 1) [Member]	Sep. 30, 2012 Fair Value, Measurements, Recurring [Member] Quoted Prices in Active Markets (Level 1) [Member]	Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Quoted Prices in Active Markets (Level 1) [Member]	Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Significant Observable Inputs (Level 2) [Member]	Sep. 30, 2012 Fair Value, Measurements, Recurring [Member] Significant Observable Inputs (Level 2) [Member]	Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Significant Observable Inputs (Level 2) [Member]	Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Significant Unobservable Inputs (Level 3) [Member]	Sep. 30, 2012 Fair Value, Measurements, Recurring [Member] Significant Unobservable Inputs (Level 3) [Member]	Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Significant Unobservable Inputs (Level 3) [Member]	Mar. 31, 2013 Fair Value, Measurements, Recurring [Member] Effects of Netting and Cash Margin Receivables Payables [Member]	Sep. 30, 2012 Fair Value, Measurements, Recurring [Member] Effects of Netting and Cash Margin Receivables Payables [Member]	Mar. 31, 2012 Fair Value, Measurements, Recurring [Member] Effects of Netting and Cash Margin Receivables Payables [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
U. S. Stock/Bond Mutual Funds					$ 13,922	$ 13,187	$ 17,907	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0	$ 0
NYMEX/ICE natural gas contracts- Asset					11,010	7,411	5,182	379	994	1,310	0	0	0	(8,209)	(8,405)	(4,881)
NYMEX gasoline and heating oil contracts- Asset					322	344	81	0	0	0	0	0	0	(192)	(344)	(81)
Natural gas commodity contracts- Asset					0	0	0	2,888	3,060	4,362	117	113	79	(289)	(299)	(538)
Total Assets					25,254	20,942	23,170	3,267	4,054	5,672	117	113	79	(8,690)	(9,048)	(5,500)
NYMEX/ICE natural gas contracts- Liabilities					2,447	12,253	37,811	1,342	1,891	2,342	0	0	0	(3,789)	(14,144)	(40,153)
Natural gas commodity contracts- Liabilities					0	0	0	990	428	1,190	24	4	21	(289)	(299)	(538)
Interest Rate Swaps					0			4,549			0			0
Total Liabilities					2,447	12,253	37,811	6,881	2,319	3,532	24	4	21	(4,078)	(14,443)	(40,691)
Beginning of period	30	37	109	13
Settlements	37	(41)	(29)	(7)
Net Gain Loss From Derivatives Not Held At End Of Period	0	(1)	0	(4)
Net gains related to derivatives still held at end of period	26	63	13	56
End of period	$ 93	$ 58	$ 93	$ 58

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EARNINGS PER COMMON SHARE (Tables)

6 Months Ended

Mar. 31, 2013

Earnings Per Share [Abstract]

Earnings Per Common Share

	Three Months Ended March 31,				Six Months Ended March 31,
(Thousands, Except Per Share Amounts)	2013		2012		2013		2012
Basic EPS:
Net Income	$	30,242	$	29,684	$	55,810	$	54,858
Less: Income allocated to participating securities	186		167		312		324
Net Income Available to Common Shareholders	$	30,056	$	29,517	$	55,498	$	54,534
Weighted Average Shares Outstanding	22,421		22,254		22,396		22,223
Earnings Per Share of Common Stock	$	1.34	$	1.33	$	2.48	$	2.45
Diluted EPS:
Net Income	$	30,242	$	29,684	$	55,810	$	54,858
Less: Income allocated to participating securities	186		166		311		323
Net Income Available to Common Shareholders	$	30,056	$	29,518	$	55,499	$	54,535
Weighted Average Shares Outstanding	22,421		22,254		22,396		22,223
Dilutive Effect of Stock Options, Restricted Stock,
and Restricted Stock Units	77		82		70		76
Weighted Average Diluted Shares	22,498		22,336		22,466		22,299
Earnings Per Share of Common Stock	$	1.34	$	1.32	$	2.47	$	2.45
Outstanding Shares Excluded from the
Calculation of Diluted EPS Attributable to:
Restricted stock and stock units subject to
performance and/or market conditions	211		203		211		203

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Part 1) (Details) (USD $)	6 Months Ended
	Mar. 31, 2013 MMBTU gal	Sep. 30, 2012	Mar. 31, 2012
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Maximum percentage of normal volumes hedged	70.00%
Maximum number of months normal volumes can be hedged (in months)	36-month
Derivative [Line Items]
Gasoline futures contracts notional amount (in gallons)	500,000
Average price of gasoline futures contracts (dollars per gallon)	$ 2.30
Notional amount of non-exchange traded natural gas commodity contracts (in MMBtu)	69,600,000
Notional amount of non-exchange traded natural gas commodity contracts to be settled during fiscal 2014 (in MMBtu)	9,800,000
Notional amount of non-exchange traded natural gas commodity contracts to be settled during fiscal 2013 (in MMBtu)	59,800,000
Notional Amount of Interest Rate Swap Derivatives	355,000,000
Derivative, Lower Fixed Interest Rate Range	1.28%
Derivative, Higher Fixed Interest Rate Range	3.14%
Expected pre-tax unrealized gain (loss) reclassifications into the Statements of Consolidated Income during the twelve months	3,100,000
Derivative instrument assets reconciliation [Abstract]
Fair value of asset derivatives presented above	14,716,000	11,922,000	11,014,000
Fair value of cash margin receivables offset with derivatives	2,928,000	5,478,000	35,648,000
Netting of assets and liabilities with the same counterparty	(11,618,000)	(14,526,000)	(41,148,000)
Derivative Assets	6,026,000	2,874,000	5,514,000
Derivative Instrument Assets, per Consolidated Balance Sheets: [Abstract]
Derivative instrument assets	6,021,000	2,855,000	5,297,000
Other deferred charges derivative instruments	5,000	19,000	217,000
Derivative Assets	6,026,000	2,874,000	5,514,000
Fair value of liability derivatives presented above	9,352,000	14,576,000	41,364,000
Fair value of cash margin payables offset with derivatives	7,540,000	83,000	457,000
Netting of assets and liabilities with the same counterparty	(11,618,000)	(14,526,000)	(41,148,000)
Derivative instrument liabilities, per Consolidated Balance Sheets	5,274,000	133,000	673,000
Cash margin receivables not offset with derivatives	1,300,000	10,000,000	8,200,000
Laclede Gas Company [Member]
Derivative [Line Items]
Nonmonetary Notional Amount Of Option Based Price Risk Derivatives	14,200,000
Laclede Gas Company [Member] | Fiscal 2013 [Member] | Open Short Futures Positions [Member]
Derivative [Line Items]
MMBtu	0
Avg. Price Per MMBtu	0.00
Laclede Gas Company [Member] | Fiscal 2013 [Member] | Open Long Futures Positions [Member]
Derivative [Line Items]
MMBtu	7,580,000
Avg. Price Per MMBtu	3.40
Laclede Gas Company [Member] | Fiscal 2014 [Member] | Open Short Futures Positions [Member]
Derivative [Line Items]
MMBtu	0
Avg. Price Per MMBtu	0.00
Laclede Gas Company [Member] | Fiscal 2014 [Member] | Open Long Futures Positions [Member]
Derivative [Line Items]
MMBtu	4,870,000
Avg. Price Per MMBtu	3.97
Laclede Energy Resources [Member]
Derivative [Line Items]
Nonmonetary Notional Amount Of Option Based Price Risk Derivatives	1,500,000
Laclede Energy Resources [Member] | Fiscal 2013 [Member] | Open Short Futures Positions [Member]
Derivative [Line Items]
MMBtu	4,360,000
Avg. Price Per MMBtu	3.61
Laclede Energy Resources [Member] | Fiscal 2013 [Member] | Open Long Futures Positions [Member]
Derivative [Line Items]
MMBtu	770,000
Avg. Price Per MMBtu	3.71
Laclede Energy Resources [Member] | Fiscal 2014 [Member] | Open Short Futures Positions [Member]
Derivative [Line Items]
MMBtu	3,260,000
Avg. Price Per MMBtu	3.86
Laclede Energy Resources [Member] | Fiscal 2014 [Member] | Open Long Futures Positions [Member]
Derivative [Line Items]
MMBtu	650,000
Avg. Price Per MMBtu	3.01
Other Deferred Charges [Member] | Natural Gas Commodity Contracts [Member] | Not Designated as Hedging Instrument [Member]
Derivative instrument assets reconciliation [Abstract]
Fair value of asset derivatives presented above		19,000	217,000
Derivative Instrument Assets, per Consolidated Balance Sheets: [Abstract]
Fair value of liability derivatives presented above		0	0
Derivative Instruments Assets [Member] | Natural Gas Commodity Contracts [Member] | Not Designated as Hedging Instrument [Member]
Derivative instrument assets reconciliation [Abstract]
Fair value of asset derivatives presented above	2,943,000	3,150,000	4,176,000
Derivative Instrument Assets, per Consolidated Balance Sheets: [Abstract]
Fair value of liability derivatives presented above	$ 227,000	$ 295,000	$ 490,000

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FAIR VALUE MEASUREMENTS (Tables)

6 Months Ended

Mar. 31, 2013

Fair Value Disclosures [Abstract]

Fair Value Measurements, Measured on Recurring Basis

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 March 31, 2013
Assets
U. S. Stock/Bond Mutual Funds	$	13,922	$	—	$	—	$	—		$	13,922
NYMEX/ICE natural gas contracts	11,010		379		—		(8,209		)	3,180
NYMEX gasoline and heating
oil contracts	322		—		—		(192		)	130
Natural gas commodity contracts	—		2,888		117		(289		)	2,716
Total	$	25,254	$	3,267	$	117	$	(8,690	)	$	19,948
Liabilities
NYMEX/ICE natural gas contracts	$	2,447	$	1,342	$	—	$	(3,789	)	$	—
Natural gas commodity contracts	—		990		24		(289		)	725
Interest rate swaps	$	—	$	4,549	$	—	$	—		$	4,549
Total	$	2,447	$	6,881	$	24	$	(4,078	)	$	5,274
As of September 30, 2012
Assets
U. S. Stock/Bond Mutual Funds	$	13,187	$	—	$	—	$	—		$	13,187
NYMEX/ICE natural gas contracts	7,411		994		—		(8,405		)	—
NYMEX gasoline and heating
oil contracts	344		—		—		(344		)	—
Natural gas commodity contracts	—		3,060		113		(299		)	2,874
Total	$	20,942	$	4,054	$	113	$	(9,048	)	$	16,061
Liabilities
NYMEX/ICE natural gas contracts	$	12,253	$	1,891	$	—	$	(14,144	)	$	—
Natural gas commodity contracts	—		428		4		(299		)	133
Total	$	12,253	$	2,319	$	4	$	(14,443	)	$	133
As of March 31, 2012
Assets
U. S. Stock/Bond Mutual Funds	$	17,907	$	—	$	—	$	—		$	17,907
NYMEX/ICE natural gas contracts	5,182		1,310		—		(4,881		)	1,611
NYMEX gasoline and heating
oil contracts	81		—		—		(81		)	—
Natural gas commodity contracts	—		4,362		79		(538		)	3,903
Total	$	23,170	$	5,672	$	79	$	(5,500	)	$	23,421
Liabilities
NYMEX/ICE natural gas contracts	$	37,811	$	2,342	$	—	$	(40,153	)	$	—
Natural gas commodity contracts	—		1,190		21		(538		)	673
Total	$	37,811	$	3,532	$	21	$	(40,691	)	$	673

Reconciliation of the Level 3 beginning and ending net derivative balances

The following is a reconciliation of the Level 3 beginning and ending net derivative balances:

	Three Months Ended March 31,					Six Months Ended March 31,
(Thousands)	2013		2012			2013			2012
Beginning of period	$	30	$	37		$	109		$	13
Settlements	37		(41		)	(29		)	(7		)
Net losses related to derivatives not held   at end of period	—		(1		)	—			(4		)
Net gains related to derivatives still held   at end of period	26		63			13			56
End of period	$	93	$	58		$	93		$	58

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

6 Months Ended

Mar. 31, 2013

Accounting Policies [Abstract]

SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES

1.        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 2012 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 flowsof 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. Laclede Energy Resources, Inc. (LER) includes its wholly owned subsidiary, LER Storage Services, Inc., which became operational on January 1, 2012.

REVENUE RECOGNITION - Laclede Gas reads meters and bills its customers on monthly cycles. The Utility records its gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at March 31, 2013 and 2012, for the Utility, were $33.3 million and $13.0 million, respectively. The amount of accrued unbilled revenue at September 30, 2012 was $11.6 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 Gas Utility Operating Revenues for the quarters ended March 31, 2013 and 2012 were $17.2 million and $15.5 million, respectively. Amounts recorded in Gas Utility Operating Revenues for the six months ended March 31, 2013 and 2012 were $27.5 million and $25.7 million, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.

NEW ACCOUNTING STANDARDS - In June 2011, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (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, did not impact total net income, comprehensive income, or earnings per share upon adoption in the first quarter of fiscal year 2013.

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.

In February 2013, the FASB issued ASU No. 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income.” This ASU amends Accounting Standards Codification (ASC) Topic 220, “Comprehensive Income,” by requiring entities to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to provide information on significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. The Company will present the new disclosures prospectively beginning in the first quarter of fiscal year 2014.

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STATEMENTS OF CONSOLIDATED COMPREHENSIVE INCOME (UNAUDITED) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012
Statement of Other Comprehensive Income [Abstract]
Net Income	$ 30,242	$ 29,684	$ 55,810	$ 54,858
Net gains (losses) on cash flow hedging derivative instruments:
Net hedging (loss) gain arising during the period	(7,590)	5,106	(6,201)	8,153
Reclassification adjustment for (gains) losses included in net income	(22)	408	2,228	(2,422)
Net unrealized gain (loss) on cash flow hedging derivative instruments	(7,612)	5,514	(3,973)	5,731
Defined benefit pension and other postretirement benefit plans:
Net actuarial loss arising during the period	0	(2,366)	0	(2,366)
Amortization of actuarial loss included in net periodic pension and postretirement benefit cost	90	3,482	181	3,573
Net defined benefit pension and other postretirement plans	90	1,116	181	1,207
Other Comprehensive Income (Loss), Before Tax	(7,522)	6,630	(3,792)	6,938
Income Tax (Benefit) Expense Related to Items of Other Comprehensive Income	(2,868)	2,561	(1,417)	2,680
Other Comprehensive Income (Loss), Net of Tax	(4,654)	4,069	(2,375)	4,258
Comprehensive Income	$ 25,588	$ 33,753	$ 53,435	$ 59,116

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COMMITMENTS AND CONTINGENCIES

6 Months Ended

Mar. 31, 2013

Commitments and Contingencies Disclosure [Abstract]

COMMITMENTS AND CONTINGENCIES

11.        COMMITMENTS AND CONTINGENCIES

Commitments

Laclede Gas and LER have entered into various contracts, expiring on dates through fiscal year 2018, for the storage, transportation, and supply of natural gas. Minimum payments required under the contracts in place at March 31, 2013 are estimated at approximately $410 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 customer relationship and work management, financial, and supply chain software applications to enhance its technology, customer service, and business processes. At March 31, 2013, the Company was contractually committed to costs of approximately $1.5 million related to this project, with additional expenditures to be incurred throughout the project’s life.

Refer to Note 12, Acquisition Agreements, for information about Laclede Group's commitments associated with the pending acquisitions of substantially all of the assets and liabilities of Missouri Gas Energy (MGE) and New England Gas Company (NEG) and the subsequent agreement with Algonquin Power & Utilities Corp. (APUC) that will allow an APUC subsidiary to acquire the Company's rights to purchase the assets of NEG.

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 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 in conjunction with other potentially responsible parties that are willing to contribute to such efforts in a meaningful and equitable fashion. Further correspondence from the Missouri Attorney General dated April 12, 2012, and November 28, 2012, encouraged Laclede Gas and other present and former owners of the site to move forward with further site investigation for possible remediation via enrollment in the Missouri Department of Natural Resources Brownfields/Voluntary Cleanup Program (BVCP) in lieu of being subjected to enforcement action by the United States Environmental Protection Agency, Region VII. Accordingly, Laclede Gas and the other former and current owners of the site each have entered into, or are in the process of entering into, Provisional Cost Sharing and Environmental Response Agreements enabling Laclede Gas to enroll the property in the BVCP and to fund and conduct additional investigation of the property. Laclede Gas enrolled the site in the BVCP as of April 1, 2013.

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 associated 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.

The MoPSC Staff previously proposed disallowances related to Laclede Gas' recovery of its purchased gas costs totaling $6.0 million pertaining to Laclede Gas' purchase of gas from a marketing affiliate, LER, applicable to fiscal years 2005 through 2007. The MoPSC Staff also proposed a number of non-monetary recommendations, based on its review of gas costs for fiscal years 2008 through 2011. Laclede Gas believes that the proposed disallowances lack merit and is vigorously opposing these adjustments. Management, after discussion with counsel, continues to believe the final outcome of these matters will not have a material effect on the Company's financial position, results of operations, or cash flows. Laclede Gas is currently in discussions with the MoPSC Staff and other parties to resolve these matters.

In connection with its review of these affiliate transactions, Laclede Gas objected, on the grounds of relevance, to MoSPC data requests seeking to obtain from LER certain of LER's proprietary documents unrelated to Laclede Gas' purchases from LER. 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 stating the Staff failed to adhere to 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. These Orders were later reversed by the Cole County Circuit Court, but ultimately upheld by the Western District Court of Appeals. On March 19, 2013, the Missouri Supreme Court declined Laclede Gas' request to review the opinion of the Western District Court of Appeals relating to the information-related requirements of the 2001 Order. As a result, additional LER documentation may need to be shared with the MoPSC staff. In addition, certain related complaints filed by the MoPSC Staff on October 6, 2010 and a counterclaim by Laclede Gas against Staff are still pending before the Commission. Management, after discussion with counsel, continues to believe the final outcome of these matters will not have a material effect on the Company's financial position, results of operations, or cash flows. Laclede Gas is currently in discussions with the MoPSC Staff and other parties to resolve these matters.

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, or cash flows 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. On January 31, 2013, the bankruptcy trustee received approval from the court to make certain additional distributions to customers. As a result of this action, Laclede Gas and LER received partial cash distributions totaling $0.7 million and $0.1 million, respectively, in April 2013. As of April 29, 2013, Laclede Gas and LER had $0.9 million and $0.2 million, respectively, on deposit with MF Global that remain unavailable pending final resolution by the bankruptcy trustee. Regarding the funds that remain outstanding after this partial distribution, management is currently unable to predict when, or to what extent, these funds will be returned. Management does not believe that the Company's exposure is material.

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.

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Document and Entity Information (USD $)	6 Months Ended
	Mar. 31, 2013	Apr. 26, 2013	Mar. 31, 2012
Document and Entity Information [Abstract]
Entity Registrant Name	Laclede Group Inc.
Entity Central Index Key	0001126956
Current Fiscal Year End Date	--09-30
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float			$ 814,739,902
Entity Common Stock, Shares Outstanding		22,671,392
Document Fiscal Year Focus	2013
Document Fiscal Period Focus	Q2
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2013

XML

ACQUISITION AGREEMENTS

6 Months Ended

Mar. 31, 2013

Business Combinations [Abstract]

ACQUISITION AGREEMENTS

12.    ACQUISITION AGREEMENTS

On December 14, 2012, Laclede Group entered into purchase and sale agreements, subject to customary closing adjustments, to acquire for $1.035 billion (collectively, the Transaction) from Southern Union Company (SUG), an affiliate of Energy Transfer Equity, L.P. and Energy Transfer Partners, L.P., substantially all of the assets and liabilities of SUG's MGE and NEG divisions (collectively, the Utilities). The Utilities are engaged in the distribution of natural gas on a regulated basis in western Missouri and in southeastern Massachusetts.

The Transaction is targeted to close before the end of fiscal year 2013, subject to customary closing conditions, including regulatory approvals from the MoPSC and the Massachusetts Department of Public Utilities. On January 22, 2013, the Federal Trade Commission notified the Company of the early termination of the waiting period under the Hart-Scott-Rodino Antitrust Improvements Act of 1976, as amended. No shareholder approval is required to complete the Transaction, and each of the entities has received all necessary approvals from their boards of directors.

The purchase and sale agreements contain certain termination rights for both the Company and SUG, including, among others, the right to terminate if the Transaction is not completed by October 14, 2013 (subject to up to four 30-day extensions under certain circumstances related to obtaining required regulatory approvals). In the event that SUG terminates the MGE acquisition agreement as a result of the failure of Laclede Group to obtain financing, the Company may be required to pay SUG a "reverse break up" fee of $73.1 million, which amount will operate as liquidated damages and a cap on such liability for such breach.

Laclede Group's agreement to acquire MGE for $975 million, via the newly formed wholly owned subsidiary Plaza Missouri Acquisition, Inc., was assigned by Laclede Group to Laclede Gas on January 11, 2013. Subsequently, on January 14, 2013, the Company filed an application with the MoPSC for approval to acquire the assets of MGE from SUG, and the Company continues to work with the MoPSC staff to respond to their requests for additional information supporting the Company's pending application.

Similarly, the agreement to acquire NEG for $60 million, including approximately $19.5 million of assumed NEG debt, is contracted through a second newly formed wholly owned subsidiary of Laclede Group, Plaza Massachusetts Acquisition, Inc. (Plaza Massachusetts). On February 11, 2013, the Company announced that it entered into an agreement with Algonquin Power & Utilities Corp. (APUC) that will allow an APUC subsidiary, through its acquisition of the stock of Plaza Massachusetts, to acquire the rights to purchase the assets of NEG, subject to certain approvals and conditions. Under the terms of this agreement, the Company will receive $11 million from APUC at closing. Further, APUC has deposited $3.0 million in an escrow account that will be paid to SUG at closing. The sale of NEG to APUC is subject to approval from the Massachusetts Department of Public Utilities (MDPU), and a filing that was made by the Company and SUG with the MDPU on January 24, 2013, for approval of the acquisition of NEG, was amended on February 19, 2013 to include APUC. On March 15, 2013, the MDPU issued a procedural schedule setting the case for hearing during the last week in June 2013. Laclede Group remains obligated to acquire NEG in the event that APUC is not able to satisfy all conditions for closing on or before October 14, 2013, although the Company believes this scenario would be unlikely. The Company's agreement with APUC is not anticipated to impact the MGE transaction.

The Transaction is supported by existing company cash and Laclede Group's fully committed $1.020 billion bridge facility with Wells Fargo Bank, National Association. That bridge facility was syndicated to a group of nine financial institutions in January 2013. The Company anticipates permanent financing to be a combination of long-term debt and equity.

The Company continues to incur costs associated with the evaluation, approval and financing of the Transaction. During the three and six months ended March 31, 2013, Laclede Group recorded $1.7 million and $3.9 million, respectively, net of tax, of third-party expenses associated with the Transaction.

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CONSOLIDATED BALANCE SHEETS (UNAUDITED) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Sep. 30, 2012	Mar. 31, 2012
ASSETS
Utility Plant	$ 1,538,890	$ 1,497,419	$ 1,425,922
Less: Accumulated depreciation and amortization	478,971	478,120	468,209
Net Utility Plant	1,059,919	1,019,299	957,713
Non-utility property	5,456	6,039	4,448
Other investments	52,910	50,775	54,688
Other Property and Investments	58,366	56,814	59,136
Current Assets:
Cash and cash equivalents	146,880	27,457	9,302
Accounts receivable:
Utility	148,624	64,027	100,015
Non-utility	55,925	51,042	34,915
Other	9,290	26,478	18,666
Allowance for doubtful accounts	(8,833)	(7,705)	(8,758)
Delayed customer billings	19,663	0	13,464
Inventories:
Natural gas stored underground	32,776	92,729	57,456
Propane gas	8,963	10,200	8,964
Materials and supplies at average cost	4,385	3,543	4,102
Natural gas receivable	13,470	22,377	16,351
Derivative instrument assets	6,021	2,855	5,297
Unamortized purchased gas adjustments	11,039	40,674	11,241
Deferred income taxes	2,527	0	0
Prepayments and other	9,183	9,339	6,795
Total Current Assets	459,913	343,016	277,810
Deferred Charges:
Regulatory assets	424,743	456,047	457,749
Other	6,157	5,086	5,723
Total Deferred Charges	430,900	461,133	463,472
Total Assets	2,009,098	1,880,262	1,758,131
Capitalization:
Common stock (70,000,000 shares authorized, 22,643,693, 22,539,431, and 22,489,986 shares issued, respectively)	22,644	22,539	22,490
Paid-in capital	172,736	168,607	165,056
Retained earnings	451,114	414,581	425,500
Accumulated other comprehensive loss	(6,491)	(4,116)	2,158
Total Common Stock Equity	640,003	601,611	615,204
Long-term debt (less current portion)	464,434	339,416	339,386
Total Capitalization	1,104,437	941,027	954,590
Current Liabilities:
Notes payable	0	40,100	0
Accounts payable	108,648	89,503	73,045
Advance customer billings	0	25,146	0
Current portion of long-term debt	0	25,000	25,000
Wages and compensation accrued	16,175	13,908	13,873
Dividends payable	10,059	9,831	9,697
Customer deposits	7,706	8,565	9,459
Interest accrued	6,191	8,590	8,789
Taxes accrued	44,550	11,304	25,062
Deferred income taxes	0	6,675	6,615
Other	14,015	13,502	16,220
Total Current Liabilities	207,344	252,124	187,760
Deferred Credits and Other Liabilities:
Deferred income taxes	343,016	355,509	335,215
Unamortized investment tax credits	3,006	3,113	3,219
Pension and postretirement benefit costs	191,778	196,558	163,940
Asset retirement obligations	41,512	40,368	28,313
Regulatory liabilities	83,026	56,319	53,267
Other	34,979	35,244	31,827
Total Deferred Credits and Other Liabilities	697,317	687,111	615,781
Commitments and Contingencies (Note 11)
Total Capitalization and Liabilities	$ 2,009,098	$ 1,880,262	$ 1,758,131

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FAIR VALUE MEASUREMENTS

6 Months Ended

Mar. 31, 2013

Fair Value Disclosures [Abstract]

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 March 31, 2013
Assets
U. S. Stock/Bond Mutual Funds	$	13,922	$	—	$	—	$	—		$	13,922
NYMEX/ICE natural gas contracts	11,010		379		—		(8,209		)	3,180
NYMEX gasoline and heating
oil contracts	322		—		—		(192		)	130
Natural gas commodity contracts	—		2,888		117		(289		)	2,716
Total	$	25,254	$	3,267	$	117	$	(8,690	)	$	19,948
Liabilities
NYMEX/ICE natural gas contracts	$	2,447	$	1,342	$	—	$	(3,789	)	$	—
Natural gas commodity contracts	—		990		24		(289		)	725
Interest rate swaps	$	—	$	4,549	$	—	$	—		$	4,549
Total	$	2,447	$	6,881	$	24	$	(4,078	)	$	5,274
As of September 30, 2012
Assets
U. S. Stock/Bond Mutual Funds	$	13,187	$	—	$	—	$	—		$	13,187
NYMEX/ICE natural gas contracts	7,411		994		—		(8,405		)	—
NYMEX gasoline and heating
oil contracts	344		—		—		(344		)	—
Natural gas commodity contracts	—		3,060		113		(299		)	2,874
Total	$	20,942	$	4,054	$	113	$	(9,048	)	$	16,061
Liabilities
NYMEX/ICE natural gas contracts	$	12,253	$	1,891	$	—	$	(14,144	)	$	—
Natural gas commodity contracts	—		428		4		(299		)	133
Total	$	12,253	$	2,319	$	4	$	(14,443	)	$	133
As of March 31, 2012
Assets
U. S. Stock/Bond Mutual Funds	$	17,907	$	—	$	—	$	—		$	17,907
NYMEX/ICE natural gas contracts	5,182		1,310		—		(4,881		)	1,611
NYMEX gasoline and heating
oil contracts	81		—		—		(81		)	—
Natural gas commodity contracts	—		4,362		79		(538		)	3,903
Total	$	23,170	$	5,672	$	79	$	(5,500	)	$	23,421
Liabilities
NYMEX/ICE natural gas contracts	$	37,811	$	2,342	$	—	$	(40,153	)	$	—
Natural gas commodity contracts	—		1,190		21		(538		)	673
Total	$	37,811	$	3,532	$	21	$	(40,691	)	$	673

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 March 31,					Six Months Ended March 31,
(Thousands)	2013		2012			2013			2012
Beginning of period	$	30	$	37		$	109		$	13
Settlements	37		(41		)	(29		)	(7		)
Net losses related to derivatives not held   at end of period	—		(1		)	—			(4		)
Net gains related to derivatives still held   at end of period	26		63			13			56
End of period	$	93	$	58		$	93		$	58

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.

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FAIR VALUE OF FINANCIAL INSTRUMENTS

6 Months Ended

Mar. 31, 2013

Financial Instruments, Owned, at Fair Value [Abstract]

FAIR VALUE OF FINANCIAL INSTRUMENTS

5.        FAIR VALUE OF FINANCIAL INSTRUMENTS

The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis are as follows:

					Classification of Estimated Fair Value
(Thousands)	Carrying Amount		Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
As of March 31, 2013
Cash and cash equivalents	$	146,880	$	146,880	$	136,826	$	10,054	$	—
Short-term debt	—		—		—		—		—
Long-term debt, including current portion	464,434		539,260		—		539,260		—
As of September 30, 2012
Cash and cash equivalents	$	27,457	$	27,457	$	17,380	$	10,077	$	—
Short-term debt	40,100		40,100		—		40,100		—
Long-term debt, including current portion	364,416		452,768		—		452,768		—
As of March 31, 2012
Cash and cash equivalents	$	9,302	$	9,302	$	4,261	$	5,041	$	—
Short-term debt	—		—		—		—		—
Long-term debt, including current portion	364,386		432,098		—		432,098		—

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. Refer to Note 6, Fair Value Measurements, for information on financial instruments measured at fair value on a recurring basis.

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Tables)

6 Months Ended

Mar. 31, 2013

Financial Instruments, Owned, at Fair Value [Abstract]

Fair value - financial instruments

The carrying amounts and estimated fair values of financial instruments not measured at fair value on a recurring basis are as follows:

					Classification of Estimated Fair Value
(Thousands)	Carrying Amount		Fair Value		Quoted Prices in Active Markets (Level 1)		Significant Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)
As of March 31, 2013
Cash and cash equivalents	$	146,880	$	146,880	$	136,826	$	10,054	$	—
Short-term debt	—		—		—		—		—
Long-term debt, including current portion	464,434		539,260		—		539,260		—
As of September 30, 2012
Cash and cash equivalents	$	27,457	$	27,457	$	17,380	$	10,077	$	—
Short-term debt	40,100		40,100		—		40,100		—
Long-term debt, including current portion	364,416		452,768		—		452,768		—
As of March 31, 2012
Cash and cash equivalents	$	9,302	$	9,302	$	4,261	$	5,041	$	—
Short-term debt	—		—		—		—		—
Long-term debt, including current portion	364,386		432,098		—		432,098		—

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SUMMARY OF SIGNIFICANT ACCOUNTING POLICIES (Policies)

6 Months Ended

Mar. 31, 2013

Accounting Policies [Abstract]

REVENUE RECOGNITION

REVENUE RECOGNITION - Laclede Gas reads meters and bills its customers on monthly cycles. The Utility records its gas utility revenues from gas sales and transportation services on an accrual basis that includes estimated amounts for gas delivered, but not yet billed. The accruals for unbilled revenues are reversed in the subsequent accounting period when meters are actually read and customers are billed. The amounts of accrued unbilled revenues at March 31, 2013 and 2012, for the Utility, were $33.3 million and $13.0 million, respectively. The amount of accrued unbilled revenue at September 30, 2012 was $11.6 million.

GROSS RECEIPTS TAXES

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 Gas Utility Operating Revenues for the quarters ended March 31, 2013 and 2012 were $17.2 million and $15.5 million, respectively. Amounts recorded in Gas Utility Operating Revenues for the six months ended March 31, 2013 and 2012 were $27.5 million and $25.7 million, respectively. Gross receipts taxes are expensed by the Utility and included in the Taxes, other than income taxes line.

NEW ACCOUNTING STANDARDS

NEW ACCOUNTING STANDARDS - In June 2011, the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (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, did not impact total net income, comprehensive income, or earnings per share upon adoption in the first quarter of fiscal year 2013.

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.

In February 2013, the FASB issued ASU No. 2013-02, “Reporting of Amounts Reclassified Out of Accumulated Other Comprehensive Income.” This ASU amends Accounting Standards Codification (ASC) Topic 220, “Comprehensive Income,” by requiring entities to provide information about the amounts reclassified out of accumulated other comprehensive income by component. In addition, an entity is required to provide information on significant amounts reclassified out of accumulated other comprehensive income by the respective line items of net income, but only if the amount reclassified is required under U.S. GAAP to be reclassified to net income in its entirety in the same reporting period. The Company will present the new disclosures prospectively beginning in the first quarter of fiscal year 2014.

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OTHER INCOME AND (INCOME DEDUCTIONS) - NET

6 Months Ended

Mar. 31, 2013

Other Nonoperating Income (Expense) [Abstract]

OTHER INCOME AND (INCOME DEDUCTIONS) - NET

9.        OTHER INCOME AND (INCOME DEDUCTIONS) - NET

	Three Months Ended March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013		2012
Interest income	$	257		$	316		$	663	$	664
Net investment (loss) gain	1,174			1,164			1,104		2,194
Other income	9			11			77		11
Other income deductions	(100		)	(110		)	580		451
Other Income and (Income Deductions) – Net	$	1,340		$	1,381		$	2,424	$	3,320

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES

6 Months Ended

Mar. 31, 2013

Derivative Instruments and Hedging Activities Disclosure [Abstract]

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 March 31, 2013, Laclede Gas held 0.5 million gallons of gasoline futures contracts at an average price of $2.30 per gallon. Most of these contracts, the longest of which extends to April 2014, are designated as cash flow hedges of forecasted transactions pursuant to ASC Topic 815. 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 gas marketing subsidiary, LER, which includes its wholly owned subsidiary LER Storage Services, Inc., enters into commitments associated with the purchase or sale of natural gas. Certain 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 March 31, 2013, the fair values of 69.6 million MMBtu of non-exchange traded natural gas commodity contracts were reflected in the Consolidated Balance Sheet. Of these contracts, 59.8 million MMBtu will settle during fiscal year 2013, while the remaining 9.8 million MMBtu will settle during fiscal year 2014. 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 Clear Europe (ICE) futures, swap, and option contracts to lock in margins. At March 31, 2013, 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, swap, and option contracts used to lock in margins may be designated as cash flow hedges of forecasted transactions for financial reporting purposes.

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 March 31, 2013 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 2013	—	$	—	4.36	$	3.61
Fiscal 2014	—	—		3.26	3.86
Open long futures positions
Fiscal 2013	7.58	$	3.40	0.77	$	3.71
Fiscal 2014	4.87	3.97		0.65	3.01

At March 31, 2013, Laclede Gas and LER also had 14.2 million MMBtu and 1.5 million MMBtu, respectively, of other price mitigation in place through the use of NYMEX natural gas option-based strategies.

In February 2013, Laclede Group entered into certain interest rate swap agreements to effectively lock in interest rates on a portion of the long-term debt it anticipates issuing to finance its pending acquisition of Missouri Gas Energy (MGE). These derivative instruments have been designated as cash flow hedges of forecasted transactions. These forward starting swaps involve the payment of a fixed interest rate and the receipt of a floating interest rate (the London Interbank Offered Rate, also known as LIBOR) over the terms specified in the contracts. At March 31, 2013, the notional amount of interest rate swaps outstanding was $355 million with stated maturities ranging from 2018 to 2043 and fixed interest rates ranging between 1.28% and 3.14%.

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 March 31, 2013, it is expected that approximately $3.1 million of pre-tax unrealized losses 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 Effect of Derivative Instruments on the Statements of Consolidated Income and Statements of Consolidated Comprehensive Income
		Three Months Ended						Six Months Ended
	Location of Gain (Loss)	March 31,						March 31,
(Thousands)	Recorded in Income	2013			2012			2013			2012
Derivatives in Cash Flow Hedging Relationships
Effective portion of gain (loss) recognized in OCI on derivatives:
NYMEX/ICE natural gas contracts		$	(3,188	)	$	5,023		$	(1,855	)	$	8,020
NYMEX gasoline and heating oil contracts		147			83			203			133
Interest rate swaps		(4,549		)	—			(4,549		)	—
Total		$	(7,590	)	$	5,106		$	(6,201	)	$	8,153
Effective portion of gain (loss) reclassified from AOCI to income:
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	$	302		$	4,048		$	(1,661	)	$	10,788
	Gas Marketing Operating Expenses	(318		)	(4,445		)	(652		)	(8,369		)
Sub-total		(16		)	(397		)	(2,313		)	2,419
NYMEX gasoline and heating oil contracts	Other Gas Utility Operating Expenses	38			(11		)	85			3
Total		$	22		$	(408	)	$	(2,228	)	$	2,422
Ineffective portion of gain (loss) on derivatives recognized in income:
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	$	(87	)	$	50		$	(412	)	$	69
	Gas Marketing Operating Expenses	(44		)	(90		)	(129		)	(196		)
Sub-total		(131		)	(40		)	(541		)	(127		)
NYMEX gasoline and heating oil contracts	Other Gas Utility Operating Expenses	(31		)	28			(132		)	34
Total		$	(162	)	$	(12	)	$	(673	)	$	(93	)
Derivatives Not Designated as Hedging Instruments *
Gain (loss) recognized in income on derivatives:
Natural gas commodity contracts	Gas Marketing Operating Revenues	$	1,745		$	1,557		$	775		$	790
	Gas Marketing Operating Expenses	—			—			—			687
NYMEX/ICE natural gas contracts	Gas Marketing Operating Revenues	(1,679		)	1,478			(612		)	1,548
	Gas Marketing Operating Expenses	—			30			—			30
NYMEX gasoline and heating oil contracts	Other Income and (Income Deductions) - Net	13			12			46			13
Total		$	79		$	3,077		$	209		$	3,068

* 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 Gas 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 March 31, 2013
	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	Accounts Receivable - Other	$	520		Accounts Receivable - Other	$	2,993
NYMEX/ICE natural gas contracts	Other Deferred Charges	5			Other Deferred Charges	—
NYMEX gasoline and heating oil contracts	Derivative Instrument Assets	312			Derivative Instrument Assets	—
Interest rate swaps	Other Current Liabilities	—			Other Current Liabilities	4,549
Sub-total		837				7,542
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Derivative Instrument Assets	10,862			Derivative Instrument Assets	339
	Accounts Receivable – Other	2			Accounts Receivable – Other	457
Natural gas commodity contracts	Derivative Instrument Assets	2,943			Derivative Instrument Assets	227
	Other Current Liabilities	62			Other Current Liabilities	787
NYMEX gasoline and heating oil contracts	Derivative Instrument Assets	10			Derivative Instrument Assets	—
Sub-total		13,879				1,810
Total derivatives		$	14,716			$	9,352
Fair Value of Derivative Instruments in the Consolidated Balance Sheet at September 30, 2012
	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	Accounts Receivable - Other	$	405		Accounts Receivable - Other	$	3,413
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	334			Accounts Receivable - Other	—
Sub-total		739				3,413
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Accounts Receivable - Other	8,000			Accounts Receivable - Other	10,731
Natural gas commodity contracts	Derivative Instrument Assets	3,150			Derivative Instrument Assets	295
	Other Current Liabilities	4			Other Current Liabilities	137
	Other Deferred Charges	19			Other Deferred Charges	—
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	10			Accounts Receivable - Other	—
Sub-total		11,183				11,163
Total derivatives		$	11,922			$	14,576

Fair Value of Derivative Instruments in the Consolidated Balance Sheet at March 31, 2012
	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	$	3,545		Derivative Instrument Assets	$	3,242
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	72			Accounts Receivable - Other	—
Sub-total		3,617				3,242
Derivatives not designated as hedging instruments
NYMEX/ICE natural gas contracts	Accounts Receivable - Other	709			Accounts Receivable - Other	36,437
	Derivative Instrument Assets	2,238			Derivative Instrument Assets	474
Natural gas commodity contracts	Derivative Instrument Assets	4,176			Derivative Instrument Assets	490
	Other Deferred Charges	217			Other Deferred Charges	—
	Other Current Liabilities	48			Other Current Liabilities	721
NYMEX gasoline and heating oil contracts	Accounts Receivable - Other	9			Accounts Receivable - Other	—
Sub-total		7,397				38,122
Total derivatives		$	11,014			$	41,364

* 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:

(Thousands)	Mar. 31, 2013			Sept. 30, 2012			Mar. 31, 2012
Fair value of asset derivatives presented above	$	14,716		$	11,922		$	11,014
Fair value of cash margin receivables offset with derivatives	2,928			5,478			35,648
Netting of assets and liabilities with the same counterparty	(11,618		)	(14,526		)	(41,148		)
Total	$	6,026		$	2,874		$	5,514
Derivative Instrument Assets, per Consolidated Balance Sheets:
Derivative instrument assets	$	6,021		$	2,855		$	5,297
Other deferred charges	5			19			217
Total	$	6,026		$	2,874		$	5,514
Fair value of liability derivatives presented above	$	9,352		$	14,576		$	41,364
Fair value of cash margin payables offset with derivatives	7,540			83			457
Netting of assets and liabilities with the same counterparty	(11,618		)	(14,526		)	(41,148		)
Derivative instrument liabilities, per Consolidated Balance Sheets*	$	5,274		$	133		$	673

*    Included in the Other line of the Current Liabilities section

Additionally, at March 31, 2013, September 30, 2012, and March 31, 2012, the Company had $1.3 million, $10.0 million, and $8.2 million, respectively, in cash margin receivables not offset with derivatives, that are presented in Accounts Receivable - Other.

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CONCENTRATIONS OF CREDIT RISK

6 Months Ended

Mar. 31, 2013

Risks and Uncertainties [Abstract]

CONCENTRATIONS OF CREDIT RISK

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 $21.9 million at March 31, 2013. Net receivable amounts from these customers on the same date, reflecting netting arrangements, were $19.5 million Accounts receivable attributable to utility companies and their marketing affiliates comprised $13.7 million of total accounts receivable at March 31, 2013, while net receivable amounts from these customers, reflecting netting arrangements, were $11.6 million. LER also has concentrations of credit risk with certain individually significant counterparties. At March 31, 2013, the amounts included in accounts receivable from LER’s five largest counterparties (in terms of net accounts receivable exposure), were $23.9 million. 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 $22.4 million. Additionally, LER has concentrations of credit risk with pipeline companies associated with its natural gas receivable amounts.

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INFORMATION BY OPERATING SEGMENT

6 Months Ended

Mar. 31, 2013

Segment Reporting [Abstract]

INFORMATION BY OPERATING SEGMENT

10.        INFORMATION BY OPERATING SEGMENT

All of Laclede Group’s subsidiaries are wholly owned. In the first quarter of fiscal year 2013, the Company retitled its segment names. The Gas Utility segment, previously titled Regulated Gas Distribution, 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 Gas Marketing segment, previously titled Non-Regulated Gas Marketing, 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 became operational in January 2012 and utilizes natural gas storage contracts for providing natural gas sales. 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, among other activities, real estate development, the compression of natural gas, and financial investments in other enterprises. These operations are conducted through seven subsidiaries. Other also includes Laclede Gas’ non-regulated business activities, which are comprised of its propane storage and related services. Accounting policies are described in Note 1. Intersegment transactions include sales of natural gas from Laclede Gas to LER, propane storage services provided by Laclede Gas to Laclede Pipeline Company, sales of natural gas from LER to Laclede Gas, and propane transportation services provided by Laclede Pipeline Company to Laclede Gas.

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 also excludes the after-tax impact of costs related to unique acquisition, divestiture, and restructuring activities.

			Gas						Unallocated and
(Thousands)	Gas Utility		Marketing			Other			Eliminations			Consolidated
Three Months Ended
March 31, 2013
Revenues from external customers	$	354,097	$	41,255		$	2,261		$	—		$	397,613
Intersegment revenues	9,814		(2,332		)	319			(7,801		)	—
Total Operating Revenues	363,911		38,923			2,580			(7,801		)	397,613
Net Economic Earnings (Losses)	30,197		2,368			(51		)	—			32,514
Total assets	1,821,372		202,012			126,668			(140,954		)	2,009,098
Six Months Ended
March 31, 2013
Revenues from external customers	$	604,208	$	96,504		$	3,904		$	—		$	704,616
Intersegment revenues	10,494		4,574			578			(15,646		)	—
Total Operating Revenues	614,702		101,078			4,482			(15,646		)	704,616
Net Economic Earnings (Losses)	55,538		5,649			(440		)	—			60,747
Total assets	1,821,372		202,012			126,668			(140,954		)	2,009,098
Three Months Ended
March 31, 2012
Revenues from external customers	$	298,623	$	66,045		$	381		$	—		$	365,049
Intersegment revenues	—		1,927			259			(9,060		)	(6,874		)
Total Operating Revenues	298,623		67,972			640			(9,060		)	358,175
Net Economic Earnings	25,772		2,545			110			—			28,427
Total assets	1,680,948		177,129			151,646			(251,592		)	1,758,131
Six Months Ended
March 31, 2012
Revenues from external customers	$	549,522	$	218,022		$	1,544		$	—		$	769,088
Intersegment revenues	3		8,538			519			(9,060		)	—
Total Operating Revenues	549,525		226,560			2,063			(9,060		)	769,088
Net Economic Earnings	46,851		5,984			485			—			53,320
Total assets	1,680,948		177,129			151,646			(251,592		)	1,758,131

Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income
	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2013			2012			2013			2012
Total Net Economic Earnings above	$	32,514		$	28,427		$	60,747		$	53,320
Add: Unrealized (loss) gain on energy-related derivative
contracts, net of tax	(587		)	1,963			(1,026		)	2,244
Add:  Lower of cost or market inventory
adjustments, net of tax	—			(562		)	—			(562		)
Add:  Realized (loss) gain on economic hedges prior to sale of
the physical commodity, net of tax	(9		)	(144		)	22			(144		)
Add:  Acquisition, divestiture, and restructuring activities,
net of tax	(1,676		)	—			(3,933		)	—
Net Income	$	30,242		$	29,684		$	55,810		$	54,858

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FAIR VALUE OF FINANCIAL INSTRUMENTS (Details) (USD $) In Thousands, unless otherwise specified	Mar. 31, 2013	Sep. 30, 2012	Mar. 31, 2012	Sep. 30, 2011
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	$ 146,880	$ 27,457	$ 9,302	$ 43,277
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	146,880	27,457	9,302
Short-term debt	0	40,100	0
Long-term debt, including current portion	464,434	364,416	364,386
Estimate of Fair Value, Fair Value Disclosure [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	146,880	27,457	9,302
Short-term debt	0	40,100	0
Long-term debt, including current portion	539,260	452,768	432,098
Quoted Prices in Active Markets (Level 1) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	136,826	17,380	4,261
Short-term debt	0	0
Long-term debt, including current portion	0	0	0
Significant Observable Inputs (Level 2) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	10,054	10,077	5,041
Short-term debt	0	40,100	0
Long-term debt, including current portion	539,260	452,768	432,098
Significant Unobservable Inputs (Level 3) [Member]
Fair Value, Balance Sheet Grouping, Financial Statement Captions [Line Items]
Cash and cash equivalents	0	0	0
Short-term debt	0	0	0
Long-term debt, including current portion	$ 0	$ 0	$ 0

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STOCK-BASED COMPENSATION (Tables)

6 Months Ended

Mar. 31, 2013

Disclosure of Compensation Related Costs, Share-based Payments [Abstract]

Restricted stock and restricted stock unit activity

Time-vested restricted stock and stock unit activity for the six months ended March 31, 2013 is presented below:

	Restricted Stock/ Stock Units		Weighted Average Grant Date Fair Value
Nonvested at September 30, 2012	115,115		$	36.54
Granted	58,774		$	39.96
Vested	(20,200	)	$	30.46
Forfeited	(3,250	)	$	38.18
Nonvested at March 31, 2013	150,439		$	38.65

Activity of restricted stock and restricted stock units subject to performance and/or market conditions during the six months ended March 31, 2013 is presented below:

	Restricted Stock/ Stock Units		Weighted Average Grant Date Fair Value
Nonvested at September 30, 2012	232,403		$	30.89
Granted (maximum shares that can be earned)	108,419		$	34.48
Vested	(37,436	)	$	27.02
Forfeited	(48,782	)	$	25.71
Nonvested at March 31, 2013	254,604		$	33.98

Stock option awards activity

Stock option activity for the six months ended March 31, 2013 is presented below:

	Stock Options		Weighted Average Exercise Price		Weighted Average Remaining Contractual Term (Years)	Aggregate Intrinsic Value ($000)
Outstanding at September 30, 2012	214,000		$	31.02
Granted	—		$	—
Exercised	(49,500	)	$	29.54
Forfeited	—		$	—
Expired	—		$	—
Outstanding at March 31, 2013	164,500		$	31.47	2.1	$	1,848
Fully Vested and Expected to Vest at March 31, 2013	164,500		$	31.47	2.1	$	1,848
Exercisable at March 31, 2013	164,500		$	31.47	2.1	$	1,848

Compensation cost recognized for share-based compensation arrangements

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

	Three Months Ended March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013			2012
Total equity compensation cost	$	1,137		$	684		$	1,759		$	1,351
Compensation cost capitalized	(356		)	(221		)	(539		)	(359		)
Compensation cost recognized in net income	781			463			1,220			992
Income tax benefit recognized in net income	(298		)	(179		)	(467		)	(383		)
Compensation cost recognized in net income, net of income tax	$	483		$	284		$	753		$	609

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OTHER INCOME AND (INCOME DEDUCTIONS) - NET (Tables)

6 Months Ended

Mar. 31, 2013

Other Nonoperating Income (Expense) [Abstract]

Other Income and (Income Deductions) by Component

	Three Months Ended March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013		2012
Interest income	$	257		$	316		$	663	$	664
Net investment (loss) gain	1,174			1,164			1,104		2,194
Other income	9			11			77		11
Other income deductions	(100		)	(110		)	580		451
Other Income and (Income Deductions) – Net	$	1,340		$	1,381		$	2,424	$	3,320

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INFORMATION BY OPERATING SEGMENT (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012	Sep. 30, 2012
Segment Reporting [Abstract]
Gas Utility segment, population of service area	2,200,000		2,200,000
Number of service area counties			ten
Number of entity subsidiaries			seven
Operating Segment Information [Abstract]
Total Operating Revenues	$ 397,613	$ 358,175	$ 704,616	$ 769,088
Net economic earnings	32,514	28,427	60,747	53,320
Total assets	2,009,098	1,758,131	2,009,098	1,758,131	1,880,262
Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income [Abstract]
Total Net Economic Earnings above	32,514	28,427	60,747	53,320
Add: Unrealized gain (loss) on energy-related derivative contracts, net of tax	(587)	1,963	(1,026)	2,244
Add: Realized gain (loss) on economic hedges prior to sale of the physical commodity, net of tax	(9)	(144)	22	(144)
Add: Acquisition, divestiture, and restructuring activities, net of tax	(1,676)	0	(3,933)	0
Add: Lower of cost or market inventory adjustments, net of tax	0	(562)	0	(562)
Net Income	30,242	29,684	55,810	54,858
Gas Utility [Member]
Operating Segment Information [Abstract]
Revenues from external customers	354,097	298,623	604,208	549,522
Intersegment revenues	9,814	0	10,494	3
Total Operating Revenues	363,911	298,623	614,702	549,525
Net economic earnings	30,197	25,772	55,538	46,851
Total assets	1,821,372	1,680,948	1,821,372	1,680,948
Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income [Abstract]
Total Net Economic Earnings above	30,197	25,772	55,538	46,851
Gas Marketing [Member]
Operating Segment Information [Abstract]
Revenues from external customers	41,255	66,045	96,504	218,022
Intersegment revenues	(2,332)	1,927	4,574	8,538
Total Operating Revenues	38,923	67,972	101,078	226,560
Net economic earnings	2,368	2,545	5,649	5,984
Total assets	202,012	177,129	202,012	177,129
Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income [Abstract]
Total Net Economic Earnings above	2,368	2,545	5,649	5,984
Other [Member]
Operating Segment Information [Abstract]
Revenues from external customers	2,261	381	3,904	1,544
Intersegment revenues	319	259	578	519
Total Operating Revenues	2,580	640	4,482	2,063
Net economic earnings	(51)	110	(440)	485
Total assets	126,668	151,646	126,668	151,646
Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income [Abstract]
Total Net Economic Earnings above	(51)	110	(440)	485
Unallocated and Eliminations [Member]
Operating Segment Information [Abstract]
Revenues from external customers	0	0	0	0
Intersegment revenues	(7,801)	(9,060)	(15,646)	(9,060)
Total Operating Revenues	(7,801)	(9,060)	(15,646)	(9,060)
Net economic earnings	0	0	0	0
Total assets	(140,954)	(251,592)	(140,954)	(251,592)
Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income [Abstract]
Total Net Economic Earnings above	$ 0	$ 0	$ 0	$ 0

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CONSOLIDATED BALANCE SHEETS (UNAUDITED) (Parenthetical)	Mar. 31, 2013	Sep. 30, 2012	Mar. 31, 2012
Capitalization:
Common Stock Shares Authorized (in shares)	70,000,000	70,000,000	70,000,000
Common Stock Shares Issued (in shares)	22,643,693	22,539,431	22,489,986

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EARNINGS PER COMMON SHARE

6 Months Ended

Mar. 31, 2013

Earnings Per Share [Abstract]

EARNINGS PER COMMON SHARE

4.        EARNINGS PER COMMON SHARE

	Three Months Ended March 31,				Six Months Ended March 31,
(Thousands, Except Per Share Amounts)	2013		2012		2013		2012
Basic EPS:
Net Income	$	30,242	$	29,684	$	55,810	$	54,858
Less: Income allocated to participating securities	186		167		312		324
Net Income Available to Common Shareholders	$	30,056	$	29,517	$	55,498	$	54,534
Weighted Average Shares Outstanding	22,421		22,254		22,396		22,223
Earnings Per Share of Common Stock	$	1.34	$	1.33	$	2.48	$	2.45
Diluted EPS:
Net Income	$	30,242	$	29,684	$	55,810	$	54,858
Less: Income allocated to participating securities	186		166		311		323
Net Income Available to Common Shareholders	$	30,056	$	29,518	$	55,499	$	54,535
Weighted Average Shares Outstanding	22,421		22,254		22,396		22,223
Dilutive Effect of Stock Options, Restricted Stock,
and Restricted Stock Units	77		82		70		76
Weighted Average Diluted Shares	22,498		22,336		22,466		22,299
Earnings Per Share of Common Stock	$	1.34	$	1.32	$	2.47	$	2.45
Outstanding Shares Excluded from the
Calculation of Diluted EPS Attributable to:
Restricted stock and stock units subject to
performance and/or market conditions	211		203		211		203

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INFORMATION BY OPERATING SEGMENT (Tables)

6 Months Ended

Mar. 31, 2013

Segment Reporting [Abstract]

Schedule of operating segment information

			Gas						Unallocated and
(Thousands)	Gas Utility		Marketing			Other			Eliminations			Consolidated
Three Months Ended
March 31, 2013
Revenues from external customers	$	354,097	$	41,255		$	2,261		$	—		$	397,613
Intersegment revenues	9,814		(2,332		)	319			(7,801		)	—
Total Operating Revenues	363,911		38,923			2,580			(7,801		)	397,613
Net Economic Earnings (Losses)	30,197		2,368			(51		)	—			32,514
Total assets	1,821,372		202,012			126,668			(140,954		)	2,009,098
Six Months Ended
March 31, 2013
Revenues from external customers	$	604,208	$	96,504		$	3,904		$	—		$	704,616
Intersegment revenues	10,494		4,574			578			(15,646		)	—
Total Operating Revenues	614,702		101,078			4,482			(15,646		)	704,616
Net Economic Earnings (Losses)	55,538		5,649			(440		)	—			60,747
Total assets	1,821,372		202,012			126,668			(140,954		)	2,009,098
Three Months Ended
March 31, 2012
Revenues from external customers	$	298,623	$	66,045		$	381		$	—		$	365,049
Intersegment revenues	—		1,927			259			(9,060		)	(6,874		)
Total Operating Revenues	298,623		67,972			640			(9,060		)	358,175
Net Economic Earnings	25,772		2,545			110			—			28,427
Total assets	1,680,948		177,129			151,646			(251,592		)	1,758,131
Six Months Ended
March 31, 2012
Revenues from external customers	$	549,522	$	218,022		$	1,544		$	—		$	769,088
Intersegment revenues	3		8,538			519			(9,060		)	—
Total Operating Revenues	549,525		226,560			2,063			(9,060		)	769,088
Net Economic Earnings	46,851		5,984			485			—			53,320
Total assets	1,680,948		177,129			151,646			(251,592		)	1,758,131

Schedule of the reconciliation of consolidated net economic earnings to consolidated net income

Reconciliation of Consolidated Net Economic Earnings to Consolidated Net Income
	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2013			2012			2013			2012
Total Net Economic Earnings above	$	32,514		$	28,427		$	60,747		$	53,320
Add: Unrealized (loss) gain on energy-related derivative
contracts, net of tax	(587		)	1,963			(1,026		)	2,244
Add:  Lower of cost or market inventory
adjustments, net of tax	—			(562		)	—			(562		)
Add:  Realized (loss) gain on economic hedges prior to sale of
the physical commodity, net of tax	(9		)	(144		)	22			(144		)
Add:  Acquisition, divestiture, and restructuring activities,
net of tax	(1,676		)	—			(3,933		)	—
Net Income	$	30,242		$	29,684		$	55,810		$	54,858

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DERIVATIVE INSTRUMENTS AND HEDGING ACTIVITIES (Part 3) (Details) (USD $) In Thousands, unless otherwise specified	3 Months Ended		6 Months Ended
	Mar. 31, 2013	Mar. 31, 2012	Mar. 31, 2013	Mar. 31, 2012
Cash Flow Hedging [Member] | NYMEX Natural Gas Contracts [Member] | Gas Marketing Operating Expenses [Member]
Derivatives in Cash Flow Hedging Relationships [Abstract]
Ineffective portion of gain (loss) on derivatives recognized in income	$ (44)	$ (90)	$ (129)	$ (196)
Effective portion of gain (loss) reclassiffied from AOCI to income	(318)	(4,445)	(652)	(8,369)
Cash Flow Hedging [Member] | NYMEX Natural Gas Contracts [Member] | Other Comprehensive Income (Loss) [Member]
Derivatives in Cash Flow Hedging Relationships [Abstract]
Effective portion of gain (loss) recognized in OCI on derivatives	(3,188)	5,023	(1,855)	8,020
Cash Flow Hedging [Member] | NYMEX Natural Gas Contracts [Member] | Gas Marketing Operating Revenue [Member]
Derivatives in Cash Flow Hedging Relationships [Abstract]
Ineffective portion of gain (loss) on derivatives recognized in income	(87)	50	(412)	69
Effective portion of gain (loss) reclassiffied from AOCI to income	302	4,048	(1,661)	10,788
Cash Flow Hedging [Member] | NYMEX Gasoline and Heating Oil Contracts [Member] | Other Comprehensive Income (Loss) [Member]
Derivatives in Cash Flow Hedging Relationships [Abstract]
Effective portion of gain (loss) recognized in OCI on derivatives	147	83	203	133
Cash Flow Hedging [Member] | NYMEX Gasoline and Heating Oil Contracts [Member] | Other Gas Utility Operating Expenses [Member]
Derivatives in Cash Flow Hedging Relationships [Abstract]
Ineffective portion of gain (loss) on derivatives recognized in income	(31)	28	(132)	34
Effective portion of gain (loss) reclassiffied from AOCI to income	38	(11)	85	3
Cash Flow Hedging [Member] | Interest Rate Swap [Member] | Other Comprehensive Income (Loss) [Member]
Derivatives in Cash Flow Hedging Relationships [Abstract]
Effective portion of gain (loss) recognized in OCI on derivatives	(4,549)	0	(4,549)	0
Not Designated as Hedging Instrument [Member] | NYMEX Natural Gas Contracts [Member] | Gas Marketing Operating Expenses [Member]
Derivatives Not Designated as Hedging Instruments [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	30	0	30
Not Designated as Hedging Instrument [Member] | NYMEX Natural Gas Contracts [Member] | Gas Marketing Operating Revenue [Member]
Derivatives Not Designated as Hedging Instruments [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	(1,679)	1,478	(612)	1,548
Not Designated as Hedging Instrument [Member] | NYMEX Gasoline and Heating Oil Contracts [Member] | Other Income and (Income Deductions) - Net [Member]
Derivatives Not Designated as Hedging Instruments [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	13	12	46	13
Not Designated as Hedging Instrument [Member] | Natural Gas Commodity Contracts [Member] | Gas Marketing Operating Expenses [Member]
Derivatives Not Designated as Hedging Instruments [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	0	0	0	687
Not Designated as Hedging Instrument [Member] | Natural Gas Commodity Contracts [Member] | Gas Marketing Operating Revenue [Member]
Derivatives Not Designated as Hedging Instruments [Abstract]
Derivative Instruments Not Designated as Hedging Instruments, Gain (Loss), Net	$ 1,745	$ 1,557	$ 775	$ 790

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PENSION PLANS AND OTHER POSTRETIREMENT BENEFITS (Tables)

6 Months Ended

Mar. 31, 2013

Defined Contribution Pension and Other Postretirement Plans Disclosure [Abstract]

Net Periodic Cost

The net periodic pension costs include the following components:

	Three Months Ended						Six Months Ended
	March 31,						March 31,
(Thousands)	2013			2012			2013			2012
Service cost – benefits earned during the period	$	2,311		$	2,301		$	4,622		$	4,613
Interest cost on projected benefit obligation	4,066			4,840			8,132			9,711
Expected return on plan assets	(4,741		)	(4,899		)	(9,482		)	(9,798		)
Amortization of prior service cost	136			148			272			296
Amortization of actuarial loss	2,839			2,259			5,678			4,536
Loss on lump-sum settlement	—			3,407			—			3,407
Sub-total	4,611			8,056			9,222			12,765
Regulatory adjustment	(433		)	(484		)	(867		)	(967		)
Net pension cost	$	4,178		$	7,572		$	8,355		$	11,798

Net periodic postretirement benefit costs consisted of the following components:

	Three Months Ended March 31,						Six Months Ended March 31,
(Thousands)	2013			2012			2013			2012
Service cost – benefits earned during the period	$	2,534		$	2,015		$	5,067		$	4,030
Interest cost on accumulated postretirement benefit obligation	1,279			1,380			2,558			2,760
Expected return on plan assets	(1,081		)	(991		)	(2,162		)	(1,982		)
Amortization of transition obligation	23			34			46			68
Amortization of prior service cost (credit)	1			(518		)	2			(1,036		)
Amortization of actuarial loss	1,325			1,065			2,650			2,130
Sub-total	4,081			2,985			8,161			5,970
Regulatory adjustment	(1,699		)	(604		)	(3,398		)	(1,208		)
Net postretirement benefit cost	$	2,382		$	2,381		$	4,763		$	4,762